PIONEER NATURAL RESOURCES CO - Quarter Report: 2021 June (Form 10-Q)

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 June 30, 2021


☐			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: 1-13245

______________________________

PIONEER NATURAL RESOURCES COMPANY

(Exact name of Registrant as specified in its charter)

______________________________


Delaware						75-2702753
(State or other jurisdiction of incorporation or organization)						(I.R.S. Employer Identification No.)

777 Hidden Ridge

Irving, Texas 75038

(Address of principal executive offices and zip code)

(972) 444-9001

(Registrant's telephone number, including area code)

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

Title of each class

Trading Symbol

Name of each exchange on which registered

Common Stock, par value $.01 per share

PXD

New York Stock Exchange

Not applicable

(Former name, former address and former fiscal year, if changed since last report)

______________________________

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 ☒ No ☐

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 ☒ No ☐

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

Large accelerated filer

☒

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. ☐

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

Yes ☐ No ☒

Number of shares of Common Stock outstanding as of August 4, 2021 243,959,045

Table of Contents

PIONEER NATURAL RESOURCES COMPANY

TABLE OF CONTENTS


		Page
Cautionary Statement Concerning Forward-Looking Statements		3

Definitions of Certain Terms and Conventions Used Herein		4

PART I. FINANCIAL INFORMATION

Item 1.	Financial Statements

	Consolidated Balance Sheets as of June 30, 2021 and December 31, 2020	5

	Consolidated Statements of Operations for the three and six months ended June 30, 2021 and 2020	7

	Consolidated Statements of Equity for the three and six months ended June 30, 2021 and 2020	8

	Consolidated Statements of Cash Flows for the six months ended June 30, 2021 and 2020	10

	Notes to Consolidated Financial Statements	11

Item 2.	Management's Discussion and Analysis of Financial Condition and Results of Operations	34

Item 3.	Quantitative and Qualitative Disclosures About Market Risk	47

Item 4.	Controls and Procedures	50

PART II. OTHER INFORMATION

Item 1.	Legal Proceedings	51

Item 1A.	Risk Factors	51

Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	51

Item 6.	Exhibits	52

Signatures		53

Table of Contents

PIONEER NATURAL RESOURCES COMPANY

Cautionary Statement Concerning Forward-Looking Statements

The information in this Quarterly Report on Form 10-Q (this "Report") contains forward-looking statements that involve risks and uncertainties. When used in this document, the words "believes," "plans," "expects," "anticipates," "forecasts," "intends," "continue," "may," "will," "could," "should," "future," "potential," "estimate" or the negative of such terms and similar expressions as they relate to Pioneer Natural Resources Company ("Pioneer" or the "Company") are intended to identify forward-looking statements, which are generally not historical in nature. The forward-looking statements are based on the Company's current expectations, assumptions, estimates and projections about the Company and the industry in which the Company operates. Although the Company believes that the expectations and assumptions reflected in the forward-looking statements are reasonable as and when made, they involve risks and uncertainties that are difficult to predict and, in many cases, beyond the Company's control.

These risks and uncertainties include, among other things, volatility of commodity prices; product supply and demand; the impact of a widespread outbreak of an illness, such as the COVID-19 pandemic, on global and U.S. economic activity; competition; the ability to obtain environmental and other permits and the timing thereof; the effect of future regulatory or legislative actions on Pioneer or the industry in which it operates, including the risk of new restrictions with respect to development activities; the ability to obtain approvals from third parties and negotiate agreements with third parties on mutually acceptable terms; potential liability resulting from pending or future litigation; the costs and results of drilling and operations; availability of equipment, services, resources and personnel required to perform the Company's drilling and operating activities; access to and availability of transportation, processing, fractionation, refining, storage and export facilities; Pioneer's ability to replace reserves, implement its business plans or complete its development activities as scheduled; the risk that the Company will not fully or timely realize the expected synergies and accretion metrics from the Parsley Energy, Inc. and Double Eagle III Midco 1 LLC acquisitions; access to and cost of capital; the financial strength of counterparties to Pioneer's credit facility, investment instruments and derivative contracts and purchasers of Pioneer's oil, NGL and gas production; uncertainties about estimates of reserves, identification of drilling locations and the ability to add proved reserves in the future; the Company's ability to achieve it's emissions reduction and flaring goals; the assumptions underlying forecasts, including forecasts of production, well costs, capital expenditures, rates of return, expenses, cash flow and cash flow from purchases and sales of oil and gas, net of firm transportation commitments; sources of funding; tax rates; quality of technical data; environmental and weather risks, including the possible impacts of climate change; cybersecurity risks; the risks associated with the ownership and operation of the Company's water services business and acts of war or terrorism. These and other risks are described in Pioneer's Annual Report on Form 10-K for the year ended December 31, 2020, this and other Quarterly Reports on Form 10-Q and other filings with the United States Securities and Exchange Commission. In addition, the Company may be subject to currently unforeseen risks that may have a materially adverse effect on it.

Accordingly, no assurances can be given that the actual events and results will not be materially different than the anticipated results described in the forward-looking statements. See "Part I, Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations," "Part 1, Item 3. Quantitative and Qualitative Disclosures About Market Risk" and "Part II, Item 1A. Risk Factors" in this Report and "Part I, Item 1. Business — Competition," "Part I, Item 1. Business —Regulation," "Part I, Item 1A. Risk Factors," "Part II, Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations" and "Part II, Item 7A. Quantitative and Qualitative Disclosures About Market Risk" in the Company's Annual Report on Form 10-K for the year ended December 31, 2020 for a description of various factors that could materially affect the ability of Pioneer to achieve the anticipated results described in the forward-looking statements. Readers are cautioned not to place undue reliance on forward-looking statements, which speak only as of the date hereof. Pioneer undertakes no duty to publicly update these statements except as required by law.

Table of Contents

PIONEER NATURAL RESOURCES COMPANY

Definitions of Certain Terms and Conventions Used Herein

Within this Report, the following terms and conventions have specific meanings:

•"Bbl" means a standard barrel containing 42 United States gallons.

•"Bcf" means one billion cubic feet and is a measure of gas volume.

•"BOE" means a barrel of oil equivalent and is a standard convention used to express oil and gas volumes on a comparable oil equivalent basis. Gas equivalents are determined under the relative energy content method by using the ratio of six thousand cubic feet of gas to one Bbl of oil or natural gas liquid.

•"BOEPD" means BOE per day.

•"Brent" means Brent oil price, a major trading classification of light sweet oil that serves as a benchmark price for oil worldwide.

•"Btu" means British thermal unit, which is a measure of the amount of energy required to raise the temperature of one pound of water one degree Fahrenheit.

•"DD&A" means depletion, depreciation and amortization.

•"Dutch TTF" means Title Transfer Facility and is a virtual trading hub for gas in the Netherlands and is the primary gas pricing hub for the European gas market.

•"GAAP" means accounting principles generally accepted in the United States of America.

•"HH" means Henry Hub, a distribution hub in Louisiana that serves as the delivery location for gas futures contracts on the NYMEX.

•"Houston Ship Channel" is a benchmark pricing hub for South Texas gas.

•"MBbl" means one thousand Bbls.

•"MBOE" means one thousand BOEs.

•"Mcf" means one thousand cubic feet and is a measure of gas volume.

•"MEH" means Magellan East Houston, an oil index benchmark price of WTI at Magellan East Houston.

•"MMBtu" means one million Btus.

•"NGLs" means natural gas liquids, which are the heavier hydrocarbon liquids that are separated from the gas stream; such liquids include ethane, propane, isobutane, normal butane and natural gasoline.

•"NYMEX" means the New York Mercantile Exchange.

•"OPEC" means the Organization of Petroleum Exporting Countries.

•"Pioneer" or the "Company" means Pioneer Natural Resources Company and its subsidiaries.

•"Proved reserves" mean those quantities of oil and gas, which, by analysis of geosciences and engineering data, can be estimated with reasonable certainty to be economically producible – from a given date forward, from known reservoirs, and under existing economic conditions, operating methods, and government regulations – prior to the time at which contracts providing the right to operate expire, unless evidence indicates that renewal is reasonably certain, regardless of whether deterministic or probabilistic methods are used for the estimation. The project to extract the hydrocarbons must have commenced or the operator must be reasonably certain that it will commence the project within a reasonable time.

(i) The area of the reservoir considered as proved includes: (A) The area identified by drilling and limited by fluid contacts, if any, and (B) Adjacent undrilled portions of the reservoir that can, with reasonable certainty, be judged to be continuous with it and to contain economically producible oil or gas on the basis of available geoscience and engineering data.

(ii) In the absence of data on fluid contacts, proved quantities in a reservoir are limited by the lowest known hydrocarbons ("LKH") as seen in a well penetration unless geoscience, engineering or performance data and reliable technology establishes a lower contact with reasonable certainty.

(iii) Where direct observation from well penetrations has defined a highest known oil ("HKO") elevation and the potential exists for an associated gas cap, proved oil reserves may be assigned in the structurally higher portions of the reservoir only if geoscience, engineering or performance data and reliable technology establish the higher contact with reasonable certainty.

(iv) Reserves which can be produced economically through application of improved recovery techniques (including, but not limited to, fluid injection) are included in the proved classification when: (A) Successful testing by a pilot project in an area of the reservoir with properties no more favorable than in the reservoir as a whole, the operation of an installed program in the reservoir or an analogous reservoir, or other evidence using reliable technology establishes

the reasonable certainty of the engineering analysis on which the project or program was based; and (B) The project has been approved for development by all necessary parties and entities, including governmental entities.

(v) Existing economic conditions include prices and costs at which economic producibility from a reservoir is to be determined. The price shall be the average during the 12-month period prior to the ending date of the period covered by the report, determined as an unweighted arithmetic average of the first-day-of-the-month price for each month within such period, unless prices are defined by contractual arrangements, excluding escalations based upon future conditions.

•"SEC" means the United States Securities and Exchange Commission.

•"SoCal" is a benchmark pricing hub for Southern California gas.

•"U.S." means United States.

•"WAHA" is a benchmark pricing hub for West Texas gas.

•"WTI" means West Texas Intermediate, a light sweet blend of oil produced from fields in western Texas and is a grade of oil used as a benchmark in oil pricing.

•With respect to information on the working interest in wells, drilling locations and acreage, "net" wells, drilling locations and acres are determined by multiplying "gross" wells, drilling locations and acres by the Company's working interest in such wells, drilling locations or acres. Unless otherwise specified, wells, drilling locations and acreage statistics quoted herein represent gross wells, drilling locations or acres.

•All currency amounts are expressed in U.S. dollars.

Table of Contents

PART I. FINANCIAL INFORMATION


ITEM 1.			FINANCIAL STATEMENTS

PIONEER NATURAL RESOURCES COMPANY

CONSOLIDATED BALANCE SHEETS

(in millions)


	June 30, 2021		December 31, 2020
	(Unaudited)
ASSETS
Current assets:
Cash and cash equivalents	$	93	$	1,442
Restricted cash	49		59


Accounts receivable, net	1,670		695

Income taxes receivable	1		4
Inventories	350		224


Derivatives	4		5
Investment in affiliate	152		123
Other	40		43
Total current assets	2,359		2,595
Oil and gas properties, using the successful efforts method of accounting:
Proved properties	34,572		23,934
Unproved properties	8,511		576
Accumulated depletion, depreciation and amortization	(11,154)		(10,071)
Total oil and gas properties, net	31,929		14,439
Other property and equipment, net	1,731		1,584
Operating lease right-of-use assets	346		197


Goodwill	261		261
Derivatives	2		3
Other assets	156		150
	$	36,784	$	19,229

The financial information included as of June 30, 2021 has been prepared by management

without audit by independent registered public accountants.

The accompanying notes are an integral part of these consolidated financial statements.

Table of Contents

PIONEER NATURAL RESOURCES COMPANY

CONSOLIDATED BALANCE SHEETS (continued)

(in millions, except share data)


	June 30, 2021		December 31, 2020
	(Unaudited)
LIABILITIES AND EQUITY
Current liabilities:
Accounts payable:
Trade	$	2,293	$	928
Due to affiliates	158		102
Interest payable	52		35
Income taxes payable	18		4
Current portion of long-term debt	—		140

Derivatives	1,170		234
Operating leases	123		100
Other	459		363
Total current liabilities	4,273		1,906
Long-term debt	6,926		3,160
Derivatives	155		66
Deferred income taxes	1,541		1,366
Operating leases	238		110
Other liabilities	1,013		1,052
Equity:
Common stock, $0.01 par value; 500,000,000 shares authorized; 243,971,771 and 175,525,268 shares issued as of June 30, 2021 and December 31, 2020, respectively	2		2
Additional paid-in capital	19,088		9,323
Treasury stock at cost: 12,726 and 11,047,856 shares as of June 30, 2021 and December 31, 2020, respectively	(2)		(1,234)
Retained earnings	3,550		3,478


Total equity	22,638		11,569
Commitments and contingencies
	$	36,784	$	19,229

The financial information included as of June 30, 2021 has been prepared by management

without audit by independent registered public accountants.

The accompanying notes are an integral part of these consolidated financial statements.

Table of Contents

PIONEER NATURAL RESOURCES COMPANY

CONSOLIDATED STATEMENTS OF OPERATIONS

(in millions, except per share data)

(Unaudited)


	Three Months Ended June 30,				Six Months Ended June 30,
	2021		Revised 2020		2021		Revised 2020
Revenues and other income:
Oil and gas	$	2,682	$	600	$	4,505	$	1,695
Sales of purchased commodities	1,587		541		2,828		1,456
Interest and other income (loss), net	(20)		48		40		(158)
Derivative gain (loss), net	(832)		(356)		(1,523)		100
Gain on disposition of assets, net	2		6		13		6
	3,419		839		5,863		3,099
Costs and expenses:
Oil and gas production	316		167		568		343
Production and ad valorem taxes	153		47		266		120
Depletion, depreciation and amortization	648		416		1,121		850
Purchased commodities	1,627		572		2,882		1,600

Exploration and abandonments	10		10		29		19
General and administrative	75		60		143		116
Accretion of discount on asset retirement obligations	2		2		3		5
Interest	41		33		81		60
Other	47		90		351		175
	2,919		1,397		5,444		3,288
Income (loss) before income taxes	500		(558)		419		(189)
Income tax benefit (provision)	(120)		109		(109)		31
Net income (loss) attributable to common stockholders	$	380	$	(449)	$	310	$	(158)

Net income (loss) per share attributable to common stockholders:
Basic	$	1.62	$	(2.73)	$	1.39	$	(0.96)
Diluted	$	1.54	$	(2.73)	$	1.33	$	(0.96)

Weighted average shares outstanding:
Basic	234		165		222		165
Diluted	247		165		235		165

Dividends declared per share	$	0.56	$	0.55	$	1.12	$	1.10

The financial information included herein has been prepared by management

without audit by independent registered public accountants.

The accompanying notes are an integral part of these consolidated financial statements.

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PIONEER NATURAL RESOURCES COMPANY

CONSOLIDATED STATEMENTS OF EQUITY

(in millions, except share data and dividends per share)

(Unaudited)


		Equity Attributable To Common Stockholders
	Shares Outstanding	Common Stock		Additional Paid-in Capital		Treasury Stock		Retained Earnings		Total Equity
	(in thousands)
Balance as of December 31, 2020	164,477	$	2	$	9,323	$	(1,234)	$	3,478	$	11,569

Dividends declared ($0.56 per share)	—	—		—		—		(122)		(122)
Cumulative effect of accounting change on convertible senior notes:
Equity component	—	—		(230)		—		28		(202)
Deferred tax component	—	—		50		—		(6)		44
Exercise of long-term incentive stock options	55	—		(2)		8		—		6

Purchases of treasury stock	(99)	—		—		(13)		—		(13)


Shares issued or reissued for acquisition	51,655	—		5,644		1,238		—		6,882
Stock-based compensation costs:
Vested compensation awards, net	623	—		—		—		—		—
Compensation costs included in net loss	—	—		19		—		—		19
Compensation costs included in net loss associated with acquisition	—	—		33		—		—		33
Net loss	—	—		—		—		(70)		(70)
Balance as of March 31, 2021	216,711	2		14,837		(1)		3,308		18,146

Dividends declared ($0.56 per share)	—	—		—		—		(138)		(138)







Purchases of treasury stock	(2)	—		—		(1)		—		(1)



Shares issued or reissued for acquisition	27,187	—		4,234		—		—		4,234
Stock-based compensation costs:
Vested compensation awards, net	63	—		—		—		—		—
Compensation costs included in net income	—	—		17		—		—		17

Net income	—	—		—		—		380		380
Balance as of June 30, 2021	243,959	$	2	$	19,088	$	(2)	$	3,550	$	22,638

The financial information included herein has been prepared by management

without audit by independent registered public accountants.

The accompanying notes are an integral part of these consolidated financial statements.

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PIONEER NATURAL RESOURCES COMPANY

CONSOLIDATED STATEMENTS OF EQUITY (continued)

(in millions, except share data and dividends per share)

(Unaudited)


		Equity Attributable To Common Stockholders
	Shares Outstanding	Common Stock		Additional Paid-in Capital		Treasury Stock		Revised Retained Earnings		Total Equity
	(in thousands)
Balance as of December 31, 2019	165,547	$	2	$	9,161	$	(1,069)	$	4,042	$	12,136
Dividends declared ($0.55 per share)	—	—		—		—		(91)		(91)
Exercise of long-term incentive stock options	8	—		(1)		1		—		—
Purchases of treasury stock	(1,007)	—		—		(122)		—		(122)
Stock-based compensation costs:
Vested compensation awards, net	316	—		—		—		—		—
Compensation costs included in net income	—	—		16		—		—		16
Net income	—	—		—		—		291		291
Balance as of March 31, 2020	164,864	$	2	$	9,176	$	(1,190)	$	4,242	$	12,230

Dividends declared ($0.55 per share)	—	—		—		—		(91)		(91)
Convertible senior notes:
Equity component	—	—		230		—		—		230
Capped call	—	—		(113)		—		—		(113)
Deferred tax provision	—	—		(25)		—		—		(25)
Purchases of treasury stock	(592)	—		—		(50)		—		(50)
Stock-based compensation costs:
Issued awards	4	—		—		—		—		—
Compensation costs included in net loss	—	—		17		—		—		17
Net loss	—	—		—		—		(449)		(449)
Balance as of June 30, 2020	164,276	$	2	$	9,285	$	(1,240)	$	3,702	11,749

The financial information included herein has been prepared by management

without audit by independent registered public accountants.

The accompanying notes are an integral part of these consolidated financial statements.

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PIONEER NATURAL RESOURCES COMPANY

CONSOLIDATED STATEMENTS OF CASH FLOWS

(in millions)

(Unaudited)


	Six Months Ended June 30,
	2021		Revised 2020
Cash flows from operating activities:
Net income (loss)	$	310	$	(158)
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depletion, depreciation and amortization	1,121		850


Exploration expenses, including dry holes	3		3
Deferred income taxes	91		(20)
Gain on disposition of assets, net	(13)		(6)
Loss on early extinguishment of debt	2		27
Accretion of discount on asset retirement obligations	3		5
Interest expense	12		18
Derivative-related activity	632		69
Amortization of stock-based compensation	69		33
Investment in affiliate valuation adjustment	(29)		101
South Texas contingent consideration valuation adjustment	—		64
South Texas deficiency fee obligation	—		69
Other	81		65
Change in operating assets and liabilities, net of effects of acquisitions:
Accounts receivable	(593)		468
Inventories	(102)		34
Other assets	23		26
Accounts payable	560		(313)
Interest payable	(54)		(27)
Other liabilities	(273)		(154)
Net cash provided by operating activities	1,843		1,154
Cash flows from investing activities:
Proceeds from disposition of assets	32		7
Cash used in acquisitions, net of cash acquired	(826)		—


Additions to oil and gas properties	(1,193)		(1,034)
Additions to other assets and other property and equipment	(55)		(79)
Net cash used in investing activities	(2,042)		(1,106)
Cash flows from financing activities:
Proceeds from issuance of senior notes, net of discount	3,247		—
Proceeds from issuance of convertible senior notes	—		1,323
Purchase of derivatives related to issuance of convertible senior notes	—		(113)
Borrowings under credit facility	650		800
Repayment of credit facilities	(1,287)		(800)
Repayment of senior notes, including tender offer premiums	(3,371)		(1,198)
Payments of other liabilities	(147)		(154)
Payments of financing fees	(31)		(26)
Purchases of treasury stock	(14)		(172)
Exercise of long-term incentive plan stock options	6		—
Dividends paid	(213)		(164)
Net cash used in financing activities	(1,160)		(504)
Net decrease in cash, cash equivalents and restricted cash	(1,359)		(456)
Cash, cash equivalents and restricted cash, beginning of period	1,501		705
Cash, cash equivalents and restricted cash, end of period	$	142	$	249

The financial information included herein has been prepared by management

without audit by independent registered public accountants.

The accompanying notes are an integral part of these consolidated financial statements.

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PIONEER NATURAL RESOURCES COMPANY

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

June 30, 2021

(Unaudited)

NOTE 1. Organization and Nature of Operations

Pioneer Natural Resources Company ("Pioneer" or the "Company") is a Delaware corporation whose common stock is listed and traded on the New York Stock Exchange (the "NYSE"). The Company is a large independent oil and gas exploration and production company that explores for, develops and produces oil, natural gas liquids ("NGLs") and gas in the Permian Basin in West Texas.

NOTE 2. Basis of Presentation

Presentation. In the opinion of management, the unaudited interim consolidated financial statements of the Company as of June 30, 2021 and for the three and six months ended June 30, 2021 and 2020 include all adjustments and accruals, consisting only of normal, recurring adjustments and accruals necessary for a fair presentation of the results for the interim periods in conformity with generally accepted accounting principles in the United States ("GAAP"). The operating results for the three and six months ended June 30, 2021 are not necessarily indicative of results for a full year.

Certain information and footnote disclosures normally included in financial statements prepared in accordance with GAAP have been condensed or omitted in accordance with the rules and regulations of the United States Securities and Exchange Commission (the "SEC"). These unaudited interim consolidated financial statements should be read together with the consolidated financial statements and notes thereto included in the Company's Annual Report on Form 10-K for the year ended December 31, 2020.

Correction of previously issued financial statements. During the Company's review of its marketing contracts during the fourth quarter of 2020, the Company identified two long-term marketing contracts that should have been accounted for as derivative contracts. The contracts were entered in October 2019, each with a January 1, 2021 contract commencement date and a December 31, 2026 contract termination date. In accordance with Staff Accounting Bulletin ("SAB") No. 99, Materiality, and SAB No. 108, Considering the Effects of Prior Year Misstatements when Quantifying Misstatements in Current Year Financial Statements, the Company evaluated the misstatements and, based on an analysis of quantitative and qualitative factors, determined that the related impact was not material to the Company's June 30, 2020 consolidated financial statements; however, the Company determined that the impact of the misstatement to its interim period ending September 30, 2020 was material. In accordance with Accounting Standards Codification 250, Accounting Changes and Error Corrections, the Company has corrected the immaterial misstatement for the three and six months ended June 30, 2020 by revising the consolidated financial statements appearing herein. The net impact of these immaterial noncash corrections to the Company's previously reported consolidated financial statements for the three and six months ended June 30, 2020 is shown below (in millions, except for per share data):



	As Reported				Adjustments			As Revised
	Three Months Ended		Six Months Ended			Three Months Ended		Six Months Ended		Three Months Ended		Six Months Ended

Oil and gas revenues	$	600	$	1,695		$	—	$	—	$	600	$	1,695
Derivative gain (loss), net	$	(336)	$	117		$	(20)	$	(17)	$	(356)	$	100

Total revenues and other income	$	859	$	3,116		$	(20)	$	(17)	$	839	$	3,099
Total costs and expenses	1,397		3,288			—		—		1,397		3,288
Loss before income taxes	(538)		(172)			(20)		(17)		(558)		(189)
Income tax benefit	99		22			10		9		109		31

Net loss	$	(439)	$	(150)		$	(10)	$	(8)	$	(449)	$	(158)
Basic and diluted net loss per share attributable to common stockholders	$	(2.66)	$	(0.91)		$	(0.07)	$	(0.05)	$	(2.73)	$	(0.96)

Use of estimates in the preparation of financial statements. Preparation of the Company's unaudited interim consolidated financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities, the disclosure of contingent assets and liabilities as of the date of the financial statements and the reported amounts of revenues and expenses during the reporting periods. Depletion of oil and gas properties is calculated using estimates of proved oil and gas reserves. There are numerous uncertainties inherent in the

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(Unaudited)

estimation of quantities of proved reserves, the projection of future rates of production and the timing of development expenditures. Similarly, evaluations for impairment of goodwill and proved and unproved oil and gas properties are subject to numerous uncertainties including, among others, estimates of proved, probable and possible reserves and commodity price outlooks. Actual results could differ from the estimates and assumptions utilized.

Adoption of new accounting standards. In August 2020, the FASB issued ASU 2020-06, "Debt-Debt with Conversion and Other Options (Subtopic 470-20) and Derivatives and Hedging-Contracts in Entity's Own Equity (Subtopic 815-40): Accounting for Convertible Instruments and Contracts in an Entity's Own Equity" ("ASU 2020-06"). ASU 2020-06 simplifies the accounting for certain convertible instruments by removing the separation models for convertible debt with a cash conversion feature or convertible instruments with a beneficial conversion feature. Additionally, ASU 2020-06 amends the diluted earnings per share calculation for convertible instruments by requiring the use of the if-converted method. The if-converted method assumes the conversion of convertible instruments occurs at the beginning of the reporting period and diluted weighted average shares outstanding includes the common shares issuable upon conversion of the convertible instruments. The Company early adopted ASU 2020-06 on January 1, 2021.

Upon issuance of the Company's $1.3 billion principal amount of 0.25% convertible senior notes due 2025 (the "Convertible Notes") in May 2020, the Company bifurcated the debt and equity components of the Convertible Notes to long-term debt and additional paid-in capital in its consolidated balance sheet. The amount recorded to additional paid in capital represented a debt discount that was being amortized to interest expense over the life of the Convertible Notes. As part of the adoption of ASU 2020-06, the Company (i) reversed the debt discount and related deferred income tax liability recorded to additional paid-in capital of $230 million and $50 million, respectively, (ii) recorded a cumulative effect of the adoption of ASU 2020-06 of $22 million to retained earnings, representing a reversal of $28 million of the debt discount that was amortized to interest expense, net of an associated deferred income tax impact of $6 million, in 2020 and (iii) recorded the respective offsets for items (i) and (ii) above, representing the unamortized debt discount attributable to the Convertible Notes of $202 million to long-term debt and the associated deferred tax impact of $44 million to deferred income tax liabilities. See Note 7 for additional information.

Additionally, upon adoption of ASU 2020-06, the treasury stock method utilized by the Company to calculate earnings per share through December 31, 2020 will no longer be allowed. As such, the Company has transitioned to the if-converted method utilizing the modified retrospective approach, resulting in 12 million incremental shares being included in the Company's weighted-average diluted shares outstanding as of June 30, 2021. See Note 16 for additional information.

NOTE 3. Acquisitions and Divestitures

Acquisitions.

DoublePoint Acquisition. On May 4, 2021, the Company acquired Double Eagle III Midco 1 LLC ("DoublePoint") pursuant to a definitive membership interest purchase agreement to acquire DoublePoint dated April 1, 2021 (the "DoublePoint Acquisition") in exchange for 27 million shares of Pioneer common stock and $1 billion of cash. The Pioneer stock consideration transferred had a fair value of $4 billion.

Parsley Acquisition. On January 12, 2021, the Company acquired Parsley Energy, Inc., a Delaware corporation that previously traded on the NYSE under the symbol "PE" ("Parsley"), pursuant to the Agreement and Plan of Merger, dated as of October 20, 2020, among Pioneer, certain of its subsidiaries, Parsley and Parsley's subsidiary, Parsley Energy, LLC (the "Parsley Acquisition"). On the closing date of the Parsley Acquisition, Parsley merged into a newly formed wholly-owned subsidiary of the Company, and the subsidiaries of Parsley, including Jagged Peak Energy LLC ("Jagged Peak"), became indirect subsidiaries of the Company.

As part of the Parsley Acquisition, each eligible share of Parsley Class A common stock and each membership interest unit of Parsley Energy, LLC were automatically converted into the right to receive 0.1252 (the "Exchange Ratio") shares of Pioneer common stock. As a result, the Company issued 52 million shares of Pioneer common stock upon the consummation of the Parsley Acquisition, representing total stock consideration transferred of approximately $7 billion.

Both the Parsley Acquisition and the DoublePoint Acquisition were accounted for using the acquisition method under ASC Topic 805, Business Combinations, which requires all assets acquired and liabilities assumed to be recorded at fair value at the acquisition date. Provisional fair value measurements were made for acquired assets and liabilities, and adjustments to

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

June 30, 2021

(Unaudited)

those measurements may be made in subsequent periods (up to one year from the acquisition date) as information necessary to complete the fair value analysis is obtained.

The following table summarizes the provisional fair values assigned to assets acquired and liabilities assumed (presented in millions):


	Parsley Acquisition		DoublePoint Acquisition
	As of January 12, 2021		As of May 4, 2021
Cash and cash equivalents (a)	$	118	$	58
Accounts receivable	252		131
Derivatives	8		—
Proved properties	5,110		3,928
Unproved properties	5,622		2,406
Other property and equipment	117		73
Operating lease right-of-use assets	201		2
Other assets	22		11
Total assets acquired	11,450		6,609

Accounts payable	335		232
Interest payable	49		22
Derivatives	317		86
Operating leases	201		2
Deferred income taxes	127		—
Long-term debt	3,238		975
Other liabilities	300		58
Total liabilities assumed	4,567		1,375
Net assets acquired	$	6,883	$	5,234

______________________

(a)Cash used in the acquisition of Parsley and DoublePoint includes $1 billion of cash used to acquire DoublePoint and $2 million of cash used in the settlement of partial shares related to the conversion of Parsley Class A common stock at the Exchange Ratio.

The following unaudited pro forma summary presents the results of operations as if the Parsley Acquisition and DoublePoint Acquisition had occurred on January 1, 2020. The pro forma summary uses estimates and assumptions based on information available at the time. Management believes the estimates and assumptions to be reasonable; however, actual results may have differed significantly from this pro forma financial information. The pro forma information does not reflect any synergy savings that might have been achieved from combining the operations and is not intended to reflect the actual results that would have occurred had the companies actually been combined during the periods presented.


	Three Months Ended June 30,				Six Months Ended June 30,
	2021		2020		2021		2020
	(in millions)				(in millions)
Revenues and other income	$	3,465	$	751	$	5,911	$	4,629
Net income (loss)	$	394	$	(909)	$	165	$	(3,830)

Divestitures.

•In March 2021, the Company sold its well services business to a third party for (i) net cash proceeds of $20 million and (ii) up to $4 million of additional cash proceeds to be earned over the next three years. The Company recorded a gain on sale of $9 million, which is reflected in net gain on disposition of assets in the consolidated statements of operations for the six months ended June 30, 2021.

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June 30, 2021

(Unaudited)

•In May 2020, the Company completed the sale of certain vertical wells and approximately 1,500 undeveloped acres in Upton County of the Permian Basin to an unaffiliated third party for net cash proceeds of $6 million. The Company recorded a gain of $6 million associated with the sale which is reflected in net gain on disposition of assets in the consolidated statements of operations for the six months ended June 30, 2020.

NOTE 4. Fair Value Measurements

The Company determines fair value based on the price that would be received from selling an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. Fair value measurements are based upon inputs that market participants use in pricing an asset or liability, which are characterized according to a hierarchy that prioritizes those inputs based on the degree to which they are observable. Observable inputs represent market data obtained from independent sources, whereas unobservable inputs reflect a company's own market assumptions, which are used if observable inputs are not reasonably available without undue cost and effort. The fair value input hierarchy level to which an asset or liability measurement in its entirety falls is determined based on the lowest level input that is significant to the measurement in its entirety.

The three input levels of the fair value hierarchy are as follows:

•Level 1 – quoted prices for identical assets or liabilities in active markets.

•Level 2 – quoted prices for similar assets or liabilities in active markets; quoted prices for identical or similar assets or liabilities in markets that are not active; inputs other than quoted prices that are observable for the asset or liability (e.g. interest rates) and inputs derived principally from or corroborated by observable market data by correlation or other means.

•Level 3 – unobservable inputs for the asset or liability, typically reflecting management's estimate of assumptions that market participants would use in pricing the asset or liability. The fair values are therefore, determined using model-based techniques, including discounted cash flow models.

Assets and liabilities measured at fair value on a recurring basis. Assets and liabilities measured at fair value on a recurring basis are as follows:


	As of June 30, 2021
	Fair Value Measurement
	Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total

	(in millions)
Assets:
Commodity price derivatives	$	—	$	6	$	—	$	6
Deferred compensation plan assets	72		—		—		72
Investment in affiliate	152		—		—		152

Total assets	224		6		—		230
Liabilities:
Commodity price derivatives	—		1,230		—		1,230
Marketing derivatives	—		—		95		95
Total liabilities	—		1,230		95		1,325
Total recurring fair value measurements	$	224	$	(1,224)	$	(95)	$	(1,095)

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June 30, 2021

(Unaudited)


	As of December 31, 2020
	Fair Value Measurement
	Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total

	(in millions)
Assets:
Commodity price derivatives	$	—	$	8	$	—	$	8
Deferred compensation plan assets	72		—		—		72
Investment in affiliate	123		—		—		123
Total assets	195		8		—		203
Liabilities:
Commodity price derivatives	—		209		—		209
Marketing derivatives	—		—		91		91
Total liabilities	—		209		91		300
Total recurring fair value measurements	$	195	$	(201)	$	(91)	$	(97)

Commodity price derivatives. The Company's commodity price derivatives represent oil, NGL and gas swap contracts, collar contracts, collar contracts with short puts, option contracts and basis swap contracts. The asset and liability measurements for the Company's commodity price derivative contracts are determined using Level 2 inputs. The Company utilizes discounted cash flow and option-pricing models for valuing its commodity price derivatives.

The asset and liability values attributable to the Company's commodity price derivatives were determined based on inputs that include (i) the contracted notional volumes, (ii) independent active market price quotes, (iii) the applicable estimated credit-adjusted risk-free rate yield curve and (iv) the implied rate of volatility inherent in the collar contracts, collar contracts with short puts and option contracts, which is based on active and independent market-quoted volatility factors.

Marketing derivatives. Under the contract terms of the marketing derivatives, the Company agreed to purchase and simultaneously sell 50 thousand barrels of oil per day at an oil terminal in Midland, Texas for a six-year term that ends on December 31, 2026. The price the Company pays to purchase the oil volumes under the purchase contract is based on a Midland West Texas Intermediate ("WTI") price and the price the Company receives for the oil volumes sold is a weighted average sales price ("WASP") that the non-affiliated counterparty receives for selling oil through their Gulf Coast storage and export facility at prices that are highly correlated with Brent oil prices during the same month of the purchase. Based on the form of the marketing contracts, the Company determined that the marketing contracts should be accounted for as derivative instruments not designated as hedges. The asset and liability measurements for the Company's marketing derivative contracts are determined using both Level 2 and 3 inputs. The Company utilizes a discounted cash flow model for valuing its marketing derivatives.

The asset and liability values attributable to the Company's marketing derivatives were determined based on Level 2 inputs that include (i) the contracted notional volumes, (ii) independent active market price quotes, (iii) the applicable estimated credit-adjusted risk-free rate yield curve and (iv) stated contractual rates. The Level 3 inputs attributable to the Company's marketing derivatives include the historical monthly differential between Brent oil prices and the corresponding WASP of the counterparty to the marketing derivatives ("WASP Differential Deduction") and, to a lesser extent, an estimated annual cost inflation rate. The average WASP Differential Deduction used in the fair value determination as of June 30, 2021 and 2020 was $2.01 and $1.93 per barrel, respectively. The WASP Differential Deduction and the estimated annual cost inflation rate reflects management's best estimate of future results utilizing historical performance, but these estimates are not observable inputs by a market participant and contain a high degree of uncertainty. The Company could experience significant mark-to-market fluctuations in the fair value of its marketing derivatives based on changes in the WASP Differential Deduction if it deviates from historical levels. For example, a 10 percent increase or decrease in the WASP Differential Deduction would impact the fair value of the Company's marketing derivatives recorded by approximately $20 million as of June 30, 2021.

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June 30, 2021

(Unaudited)

Deferred compensation plan assets. The Company's deferred compensation plan assets include investments in equity and mutual fund securities that are actively traded on major exchanges. The fair value of these investments is determined using Level 1 inputs based on observable prices on major exchanges.

Investment in affiliate. The Company elected the fair value option for measuring its equity method investment in ProPetro Holding Corp. ("ProPetro"). The fair value of its investment in ProPetro is determined using Level 1 inputs based on observable prices on a major exchange. See Note 11 and Note 13 for additional information.

Assets and liabilities measured at fair value on a nonrecurring basis. Certain assets and liabilities are measured at fair value on a nonrecurring basis. These assets and liabilities are not measured at fair value on an ongoing basis, but are subject to fair value adjustments in certain circumstances. These assets and liabilities can include inventory, proved and unproved oil and gas properties, goodwill and other long-lived assets that are written down to fair value when they are impaired or held for sale.

Parsley Acquisition and DoublePoint Acquisition. Both the Parsley Acquisition and DoublePoint Acquisition were accounted for using the acquisition method under ASC Topic 805, "Business Combinations", which requires all assets acquired and liabilities assumed in the acquisitions to be recorded at fair values at the acquisition date of each transaction. Oil and gas properties were valued based on income and market based approaches utilizing Level 3 inputs including internally generated development and production profiles and price and cost assumptions. Debt assumed in the acquisitions was valued based on Level 2 inputs that included using observable market prices to determine fair value. Net derivative liabilities assumed in the acquisitions were valued based on Level 2 inputs similar to the Company's other commodity price derivatives. See Note 3 for additional information.

South Texas Divestiture. The Company recorded a deficiency fee obligation and related deficiency fee receivable in conjunction with its 2019 divestiture of its South Texas assets (the "South Texas Divestiture"). The fair value of the deficiency fee obligation and deficiency fee receivable was determined using Level 3 inputs based on a probability-weighted forecast that considers historical results, market conditions and various development plans to arrive at the estimated present value of the deficiency payments and corresponding receipts. Changes to the Company's forecasted deficiency fee obligation resulted in the Company recording a charge of $69 million to other expense during the six months ended June 30, 2020. The present value of the estimated future cash payments and expected cash receipts were determined using a 3.6 percent and 3.2 percent discount rate, respectively, based on the estimated timing of future payments and receipts and the Company's counterparty credit risk assessments. See Note 10 and Note 14 for additional information.

Financial instruments not carried at fair value. Carrying values and fair values of financial instruments that are not carried at fair value in the consolidated balance sheets are as follows:


	As of June 30, 2021				As of December 31, 2020
	Carrying Value		Fair Value		Carrying Value		Fair Value

	(in millions)
Assets:
Cash and cash equivalents (a)	$	93	$	93	$	1,442	$	1,442


Restricted cash (a)	$	49	$	49	$	59	$	59







Liabilities:
Current portion of long-term debt:
Senior notes (b)	$	—	$	—	$	140	$	140
Long-term debt:
Convertible Notes (b) (c)	$	1,304	$	2,099	$	1,100	$	1,756
Senior notes (b)	$	5,622	$	5,737	$	2,060	$	2,230

______________________

(a)Fair value approximates carrying value due to the short-term nature of the instruments.

(b)Fair value is determined using Level 2 inputs. The Company's senior notes are quoted, but not actively traded on major exchanges; therefore, fair value is based on periodic values as quoted on major exchanges. See Note 7 for additional information.

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

June 30, 2021

(Unaudited)

(c)Upon issuance of the Convertible Notes, the debt discount and related deferred income tax liability were recorded to additional paid-in capital. As part of the Company's early adoption of ASU 2020-06 on January 1, 2021 (see Note 2), the Company reclassified the debt discount and related deferred income tax liability of $230 million and $50 million, respectively, from additional paid-in capital to the Convertible Notes reported in long-term debt and deferred income taxes, respectively, in the consolidated balance sheets.

The Company has other financial instruments consisting primarily of receivables, payables, other current assets and liabilities that approximate fair value due to the nature of the instrument and their relatively short maturities. Non-financial assets and liabilities initially measured at fair value include assets acquired and liabilities assumed in a business combination, goodwill and asset retirement obligations.

NOTE 5. Derivative Financial Instruments

Oil production derivatives. The Company sells its oil production at the lease and the sales contracts governing such oil production are tied directly to, or are correlated with, NYMEX WTI oil prices. The Company also enters into (i) pipeline capacity commitments in order to secure available oil, NGL and gas transportation capacity from its areas of production and (ii) purchase transactions with third parties and separate sale transactions with third parties to diversify a portion of the Company's oil sales to Gulf Coast refineries or international export markets at prices that are highly correlated to Brent oil prices. As a result, the Company uses a combination of Brent, Magellan East Houston ("MEH") and WTI derivative contracts to manage future oil price volatility.

The Company's outstanding oil derivative contracts as of June 30, 2021 and the weighted average oil prices per barrel for those contracts are as follows:


	2021				Year Ending December 31, 2022
	Third Quarter		Fourth Quarter






Brent swap contracts:
Volume per day (Bbl)	17,000		17,000		—
Price per Bbl	$	44.45	$	44.45	$	—
MEH swap contracts:
Volume per day (Bbl)	43,000		43,000		2,055
Price per Bbl	$	40.52	$	40.52	$	42.80
Midland WTI swap contracts:
Volume per day (Bbl)	5,000		5,000		—
Price per Bbl	$	40.50	$	40.50	$	—
NYMEX WTI swap contracts:
Volume per day (Bbl)	15,000		15,000		—
Price per Bbl	$	52.85	$	52.85	$	—
NYMEX rollfactor swap contracts:
Volume per day (Bbl)	35,000		35,000		—
Price per Bbl	$	0.17	$	0.17	$	—
Midland WTI basis swap contracts:
Volume per day (Bbl)	37,000		37,000		26,000
Price per Bbl	$	0.89	$	0.89	$	0.50
Brent call contracts sold:
Volume per day (Bbl) (a)	20,000		20,000		—
Price per Bbl	$	69.74	$	69.74	$	—

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

June 30, 2021

(Unaudited)


Brent collar contracts:
Volume per day (Bbl)	—		—		10,000
Price per Bbl:
Ceiling	$	—	$	—	$	60.32
Floor	$	—	$	—	$	50.00
NYMEX WTI collar contracts:
Volume per day (Bbl)	16,000		6,000		—
Price per Bbl:
Ceiling	$	64.66	$	55.54	$	—
Floor	$	56.25	$	50.00	$	—
Brent collar contracts with short puts:
Volume per day (Bbl) (b)	110,000		90,000		57,000
Price per Bbl:
Ceiling	$	54.46	$	50.74	$	64.41
Floor	$	47.82	$	45.11	$	50.18
Short put	$	36.87	$	35.07	$	38.25
MEH collar contracts with short puts:
Volume per day (Bbl)	9,446		9,446		—
Price per Bbl:
Ceiling	$	51.29	$	51.29	$	—
Floor	$	41.55	$	41.55	$	—
Short put	$	31.55	$	31.55	$	—
NYMEX WTI collar contracts with short puts:
Volume per day (Bbl)	—		—		12,000
Price per Bbl:
Ceiling	$	—	$	—	$	65.86
Floor	$	—	$	—	$	52.50
Short put	$	—	$	—	$	40.00

______________________

(a)The referenced call contracts were sold in exchange for higher ceiling prices on certain 2020 collar contracts with short puts.

(b)Between July 1, 2021 and July 30, 2021, the Company entered into additional derivative contracts for 10,000 Bbls per day of Brent collar contracts with short puts for January 2022 through December 2022 production with a ceiling price of $75.19 per Bbl, a floor price of $45.00 per Bbl and a short put price of $65.00 per Bbl.

NGL production derivatives. All material physical sales contracts governing the Company's NGL production are tied directly or indirectly to Mont Belvieu, Texas NGL component product prices. The Company uses derivative contracts to manage the volatility of NGL component product prices. As of June 30, 2021, the Company did not have any NGL derivative contracts outstanding.

Gas production derivatives. All material physical sales contracts governing the Company's gas production are tied directly or indirectly to NYMEX Henry Hub ("HH") gas prices or regional index prices (e.g. WAHA, SoCal and Houston Ship Channel) where the gas is sold. To diversify the gas prices it receives to international market prices, the Company sells a portion of its gas production at Dutch Title Transfer Facility ("Dutch TTF") prices. The Company uses derivative contracts to manage gas price volatility and basis swap contracts to reduce basis risk between HH prices and actual index prices at which the gas is sold. Between July 1, 2021 and July 30, 2021, the Company entered into NYMEX collar contracts with short puts of 100,000 MMBtu per day for the year ending December 2022 production with a ceiling price of $4.00 per MMBtu, a floor price of $2.50 per MMBtu and a short put price of $3.20 per MMBtu.

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PIONEER NATURAL RESOURCES COMPANY

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

June 30, 2021

(Unaudited)

The Company's outstanding gas derivative contracts as of June 30, 2021 and the weighted average gas prices per MMBtu for those contracts are as follows:


	2021				Year Ending December 31, 2022
	Third Quarter		Fourth Quarter
NYMEX swap contracts:
Volume per day (MMBtu) (a)	60,000		60,000		—
Price per MMBtu	$	2.95	$	2.95	$	—


Dutch TTF swap contracts:
Volume per day (MMBtu) (b)	30,000		30,000		—
Price per MMBtu	$	5.07	$	5.07	$	—
WAHA swap contracts:
Volume per day (MMBtu)	116,304		116,304		4,932
Price per MMBtu	$	2.36	$	2.36	$	2.46
NYMEX collar contracts:
Volume per day (MMBtu)	247,000		247,000		1,726
Price per MMBtu:
Ceiling	$	3.19	$	3.20	$	3.45
Floor	$	2.60	$	2.60	$	2.75
Basis swap contracts:
Permian Basin index swap volume per day (MMBtu) (b)	7,000		7,000		1,726
Price differential ($/MMBtu)	$	(0.39)	$	(0.39)	$	(0.39)

____________________

(a)Between July 1, 2021 and July 30, 2021, the Company entered into additional NYMEX swap contracts for 100,000 MMBtu per day of October 2021 through December 2021 production with an average fixed price of $4.04 per MMBtu.

(b)Between July 1, 2021 and July 30, 2021, the Company entered into additional Dutch TTF swap contracts for 30,000 MMBtu per day of January 2022 through December 2022 production with an average fixed price of $8.87 per MMBtu.

(c)The referenced basis swap contracts fix the basis differentials between the index price at which the Company sells a portion of its Permian Basin gas and the NYMEX index price used in swap contracts.

Marketing derivatives. The Company uses marketing derivatives to diversify its oil sales to Gulf Coast and international markets. The Company's marketing derivatives reflect two long-term marketing contracts that were entered in October 2019 whereby the Company agreed to purchase and simultaneously sell 50 thousand barrels of oil per day at an oil terminal in Midland, Texas for a six-year term that began on January 1, 2021 and ends on December 31, 2026. The price the Company pays to purchase the oil volumes under the purchase contract is based on a Midland WTI price and the price the Company receives for the oil volumes sold is a WASP that a non-affiliated counterparty receives for selling oil through their Gulf Coast storage and export facility at prices that are highly correlated with Brent oil prices during the same month of the purchase. Based on the form of the marketing contracts, the Company determined that the marketing contracts should be accounted for as derivative instruments. For the three and six months ended June 30, 2021, the Company recorded noncash marketing derivative gains of $17 million and noncash marketing derivative losses of $3 million, respectively, and cash payments of $13 million and $20 million, respectively, as compared to noncash marketing derivative losses of $21 million and $15 million, respectively, and no cash payments or receipts for the same respective periods in 2020.

Derivative accounting. The Company's derivatives are accounted for as non-hedge derivatives and therefore all changes in the fair values of its derivative contracts are recognized as gains or losses in the earnings of the periods in which they occur. The Company enters into commodity price derivatives under master netting arrangements, which, in an event of default, allows the Company to offset payables to and receivables from the defaulting counterparty.

Contingent consideration. The Company's right to receive contingent consideration in conjunction with the South Texas Divestiture was determined to be a derivative financial instrument that is not designated as a hedging instrument. Prior to its settlement in July 2020, the contingent consideration was revalued using an option pricing model each reporting period based on forecasted oil and NGL prices during each of the five years from 2020 to 2024. See Note 13 for additional information.

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PIONEER NATURAL RESOURCES COMPANY

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

June 30, 2021

(Unaudited)

Noncash gains and losses associated with the Company's (i) commodity price derivatives and marketing derivatives and (ii) contingent consideration are separately presented in operating activities within the consolidated statements of cash flows.

Fair value. The fair value of derivative financial instruments not designated as hedging instruments is as follows:


As of June 30, 2021
Type	Consolidated Balance Sheet Location	Fair Value		Gross Amounts Offset in the Consolidated Balance Sheet		Net Fair Value Presented in the Consolidated Balance Sheet


		(in millions)
Assets:
Commodity price derivatives	Derivatives - current	$	4	$	—	$	4
Commodity price derivatives	Derivatives - noncurrent	$	2	$	—	$	2

Liabilities:
Commodity price derivatives	Derivatives - current	$	1,115	$	—	$	1,115
Marketing derivatives	Derivatives - current	$	55	$	—	$	55
Commodity price derivatives	Derivatives - noncurrent	$	115	$	—	$	115
Marketing derivatives	Derivatives - noncurrent	$	40	$	—	$	40


As of December 31, 2020
Type	Consolidated Balance Sheet Location	Fair Value		Gross Amounts Offset in the Consolidated Balance Sheet		Net Fair Value Presented in the Consolidated Balance Sheet

		(in millions)
Assets:
Commodity price derivatives	Derivatives - current	$	5	$	—	$	5
Commodity price derivatives	Derivatives - noncurrent	$	3	$	—	$	3
Liabilities:
Commodity price derivatives	Derivatives - current	$	198	$	—	$	198
Marketing derivatives	Derivatives - current	$	36	$	—	$	36
Commodity price derivatives	Derivatives - noncurrent	$	11	$	—	$	11
Marketing derivatives	Derivatives - noncurrent	$	55	$	—	$	55

Fair value. Gains and losses recorded on derivative financial instruments not designated as hedging instruments are as follows:


Derivatives Not Designated as Hedging Instruments	Location of Gain/(Loss) Recognized in Earnings on Derivatives	Three Months Ended June 30,				Six Months Ended June 30,
		2021		2020		2021		2020

		(in millions)
Commodity price derivatives	Derivative gain (loss), net	$	(836)	$	(335)	$	(1,500)	$	137
Marketing derivatives	Derivative gain (loss), net	$	4	$	(21)	$	(23)	$	(15)
Interest rate derivatives	Derivative gain (loss), net	$	—	$	—	$	—	$	(22)
Contingent consideration	Interest and other income (loss), net	$	—	$	(1)	$	—	$	(64)

The Company uses credit and other financial criteria to evaluate the credit standing of, and to select, counterparties to its derivative instruments. Although the Company does not obtain collateral or otherwise secure the fair value of its derivative instruments, associated credit risk is mitigated by the Company's credit risk policies and procedures.

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PIONEER NATURAL RESOURCES COMPANY

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

June 30, 2021

(Unaudited)

NOTE 6. Exploratory Costs

The Company capitalizes exploratory well and project costs until a determination is made that the well or project has either found proved reserves, is impaired or is sold. The Company's capitalized exploratory well and project costs are included in proved properties in the consolidated balance sheets. If the exploratory well or project is determined to be impaired, the impaired costs are charged to exploration and abandonments expense.

The changes in capitalized exploratory well costs are as follows:


	Six Months Ended June 30, 2021

	(in millions)
Beginning capitalized exploratory well costs	$	498


Additions to exploratory well costs pending the determination of proved reserves	1,279
Additions to capitalized exploratory well costs from acquisitions	235


Reclassification due to determination of proved reserves	(1,364)




Ending capitalized exploratory well costs	$	648

Aging of capitalized exploratory costs and the number of projects for which exploratory well costs have been capitalized for a period greater than one year, based on the date drilling was completed, are as follows:


	As of June 30, 2021		As of December 31, 2020

	(in millions, except well counts)
Capitalized exploratory well costs that have been suspended:
One year or less	$	648	$	495
More than one year	—		3
	$	648	$	498
Number of wells or projects with exploratory well costs that have been suspended for a period greater than one year	—		1

Table of Contents

PIONEER NATURAL RESOURCES COMPANY

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

June 30, 2021

(Unaudited)

NOTE 7. Long-term Debt

The components of long-term debt, including the effects of issuance costs and issuance discounts, are as follows:


	As of June 30, 2021		As of December 31, 2020

	(in millions)
Outstanding debt principal balances:



3.45% senior notes due 2021	$	—	$	140
3.95% senior notes due 2022	244		244
0.55% senior notes due 2023	750		—
0.75% senior callable notes due 2024	750		—
0.25% convertible senior notes due 2025	1,323		1,323
1.125% senior notes due 2026	750		—
4.45% senior notes due 2026	500		500
5.625% senior notes due 2027	179		—
7.20% senior notes due 2028	241		241
4.125% senior notes due 2028	138		—
1.90% senior notes due 2030	1,100		1,100
2.15% senior notes due 2031	1,000		—
	6,975		3,548


Issuance costs and discounts, net	(49)		(248)
Total debt	6,926		3,300

Less current portion of long-term debt	—		(140)
Long-term debt	$	6,926	$	3,160

Credit facility. The Company maintains a revolving corporate credit facility (the "Credit Facility") with a syndicate of financial institutions and has aggregate loan commitments of $2.0 billion. On January 12, 2021, Pioneer entered into the First Amendment to Credit Agreement (the "Amendment") with Wells Fargo Bank, National Association, as Administrative Agent, and the other agents and lenders party thereto. The primary changes attributable to the Amendment were to increase the aggregate loan commitments from $1.5 billion to $2.0 billion, extend the maturity of the Credit Facility to January 12, 2026 and to nominally adjust the drawn and undrawn pricing. As of June 30, 2021, the Company had no outstanding borrowings under the Credit Facility and was in compliance with its debt covenants.

Assumption of DoublePoint notes and payoff of DoublePoint credit facility. In connection with the completion of the DoublePoint Acquisition, the Company assumed DoublePoint's long-term debt of $650 million in aggregate principal amount (with a fair value of $735 million) and DoublePoint's credit facility with an outstanding balance of $240 million. The Company repaid and terminated the DoublePoint credit facility agreement on May 4, 2021.

Assumption of Parsley notes and payoff of Parsley credit facility. In connection with the completion of the Parsley Acquisition, the Company assumed Parsley's long-term debt of $2.7 billion in aggregate principal amount (with a fair value of $2.8 billion) and Parsley's credit facility with an outstanding balance of $397 million. The Company repaid and terminated the Parsley credit facility agreement on January 12, 2021.

Senior notes. In May 2021, the Company issued $750 million of 0.55% senior notes that will mature May 15, 2023 (the "May 2021 Senior Notes Offering"). The Company received proceeds, net of $4 million of issuance costs and discounts, of $746 million. Interest on the notes will be payable on May 15 and November 15 of each year. The senior notes are unsecured obligations ranking equally in right of payment with all other senior unsecured indebtedness of the Company.

The Company used the proceeds from the May 2021 Senior Notes Offering to pay $731 million to redeem DoublePoint's 7.750% senior notes due 2025. Associated with the redemption, the Company recognized a $3 million gain on the early extinguishment of debt (see Note 1 4).

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PIONEER NATURAL RESOURCES COMPANY

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

June 30, 2021

(Unaudited)

In January 2021, the Company issued $750 million of 0.750% senior callable notes that will mature January 15, 2024, $750 million of 1.125% senior notes that will mature January 15, 2026 and $1 billion of 2.150% senior notes that will mature January 15, 2031 (the "January 2021 Senior Notes Offering"). The Company received proceeds, net of $24 million of issuance costs and discounts, of $2.5 billion. Interest on each of the new notes will be payable on January 15 and July 15 of each year. The senior notes are unsecured obligations ranking equally in right of payment with all other senior unsecured indebtedness of the Company.

The Company used the proceeds from the January 2021 Senior Notes Offering to pay (i) $1.6 billion to redeem Parsley's 5.250% senior notes due 2025, Parsley's 5.375% senior notes due 2025 and Jagged Peak's 5.875% senior notes due 2026 and (ii) $852 million to purchase a portion of Parsley's 5.625% senior notes due 2027 and Parsley's 4.125% senior notes due 2028 pursuant to a cash tender offer. In connection with the tender offers, the Company also obtained the requisite consents from holders of Parsley's 5.625% senior notes due 2027 and 4.125% senior notes due 2028 to amend the indentures pursuant to which the notes were issued to, among other things, (i) eliminate substantially all of the restrictive covenants and related provisions and certain events of default contained in each indenture and (ii) shorten the minimum notice requirement for optional redemptions to three days. Associated with the redemption and tenders, the Company recognized a $5 million loss on the early extinguishment of debt (see Note 14).

The Company's 3.45% senior notes with a debt principal balance of $140 million matured and were repaid in January 2021. The Company funded the repayment with cash on hand.

Convertible senior notes. In May 2020, the Company issued $1.3 billion principal amount of convertible senior notes due 2025. The Convertible Notes bear a fixed interest rate of 0.25% per year, with interest payable on May 15 and November 15 of each year. The Convertible Notes will mature on May 15, 2025, unless earlier redeemed, repurchased or converted. The Convertible Notes are unsecured obligations ranking equally in right of payment with all other senior unsecured indebtedness of the Company.

Holders of the Convertible Notes may convert their notes at their option prior to February 15, 2025 under the following circumstances:

•during the quarter following any quarter during which the last reported sales price of the Company's common stock for at least 20 of the last 30 consecutive trading days of such quarter exceeds 130 percent of the Conversion Price;

•during the five-day period following any five consecutive trading day period when the trading price of the Convertible Notes is less than 98 percent of the price of the Company's common stock times the Conversion Rate;

•upon notice of redemption by the Company; or

•upon the occurrence of specified corporate events, including certain consolidations or mergers.

On or after February 15, 2025, until the close of business on the second scheduled trading day immediately preceding the maturity date, holders may convert their notes at any time. The Company may not redeem the Convertible Notes prior to May 20, 2023, and after such date, may redeem the Convertible Notes only if the last reported sale price of the Company's common stock has been at least 130 percent of the Conversion Price for at least 20 trading days (whether or not consecutive) during any 30 consecutive trading day period ending on, and including, the trading day immediately preceding the date on which the Company provides the notice of redemption. The redemption price is equal to 100 percent of the principal amount of the Convertible Notes to be redeemed, plus accrued and unpaid interest.

During the last 30 consecutive trading days of the second quarter of 2021, the last reported sales prices of the Company's common stock exceeded 130 percent of the Conversion Price for at least 20 trading days, causing the Convertible Notes to become convertible at the option of the holders during the three month period ending September 30, 2021. As of June 30, 2021, if converted by the holder, the Company intends to settle the Convertible Notes in cash through borrowings under its Credit

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PIONEER NATURAL RESOURCES COMPANY

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

June 30, 2021

(Unaudited)

Facility. The Company reserves its right under the notes indenture to elect to settle the Convertible Notes in shares of the Company's common stock or a combination of cash and common stock.

The Company early adopted ASU 2020-06 on January 1, 2021. Upon issuance of the Convertible Notes in May 2020, the Company bifurcated the debt and equity components of the Convertible Notes between long-term debt and additional paid-in capital in its consolidated balance sheet. The amount recorded to additional paid-in capital represented a debt discount that was being amortized to interest expense over the life of the Convertible Notes. As part of the adoption of ASU 2020-06, the Company (i) reversed the debt discount and related deferred income tax liability recorded to additional paid-in capital of $230 million and $50 million, respectively, (ii) recorded a cumulative effect of the adoption of ASU 2020-06 of $22 million to retained earnings, representing the reversal of the $28 million debt discount that was amortized to interest expense, net of an associated deferred income tax impact of $6 million, in 2020 and (iii) recorded the respective offsets for items (i) and (ii) above, representing the unamortized debt discount attributable to the Convertible Notes of $202 million to long-term debt and the associated deferred tax impact of $44 million to deferred income tax liabilities. See Note 2 for additional information.

As of June 30, 2021, the Convertible Notes had an outstanding principal balance of $1.3 billion and unamortized issuance costs of $18 million. The effective interest rate related to interest expense to be recorded over the life of the Convertible Notes is 0.6 percent. See Note 2 for additional information regarding the effect of the early adoption of ASU 2020-06 on the debt discount on the Company's Convertible Notes.

The interest costs recognized on the Convertible Notes, are as follows:


	Three Months Ended June 30,				Six Months Ended June 30,
	2021		2020		2021		2020

	(in millions)
Contractual coupon interest	$	1	$	1	$	2	$	1
Amortization of debt discount and issuance costs	1		8		2		8
	$	2	$	9	$	4	$	9

Capped call transactions. In connection with the issuance of the Convertible Notes, the Company entered into privately negotiated capped call transactions with certain financial institution counterparties (the "Capped Call"), the purpose of which was to reduce the potential dilution to the Company's common stock upon conversion of the Convertible Notes and/or offset any cash payments the Company is required to make in excess of the principal amount of such converted notes, with such reduction and offset subject to a capped price. The Capped Call transactions have a strike price of $109.76 per share of common stock and a capped price of $156.19 per share of common stock. The net costs of $113 million incurred to purchase the Capped Call transactions were recorded as a reduction to additional paid-in capital. The closing price of the Company's common stock at June 30, 2021 was $162.52 which exceeded the capped price. Therefore, if the Convertible Notes were converted and settlement of the capped call transaction had occurred on June 30, 2021, the Company would have been entitled to receive $559 million in cash or 3.4 million shares of the Company's common stock, or a combination thereof.

NOTE 8. Incentive Plans

In connection with the Parsley Acquisition, the Company assumed all rights and obligations under the Amended and Restated Parsley Energy, Inc. 2014 Long Term Incentive Plan (the "2014 Parsley Plan") and the Jagged Peak Energy Inc. 2017 Long Term Incentive Plan (the "Jagged Peak Plan") and together with the 2014 Parsley Plan, (the "Parsley Plans"). The awards outstanding under the Parsley Plans were assumed by the Company and were automatically converted into an award with the right to receive a number of shares of Pioneer common stock that is equal to the product of the number of shares of Parsley common stock subject to such award under the Parsley Plans as of the acquisition date and the Exchange Ratio (0.1252). As a result, 37,299 shares of Pioneer common stock are issuable by the Company upon settlement of the outstanding awards granted under the 2014 Parsley Plan and 1,166 shares of Pioneer common stock are issuable by the Company upon settlement of the outstanding awards granted under the Jagged Peak Plan.

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PIONEER NATURAL RESOURCES COMPANY

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

June 30, 2021

(Unaudited)

The number of shares available for grant pursuant to the awards issued under the Company's Amended and Restated 2006 Long-Term Incentive Plan ("LTIP") is as follows:


			As of June 30, 2021
Approved and authorized awards			12,600,000
2014 Parsley Plan awards available to the LTIP (a)			879,575
Awards issued under the plan			(9,311,208)
Awards available for future grant			4,168,367

______________________

(a) Under New York Stock Exchange rules, the Company added the shares that were available under the 2014 Parsley Plan to the LTIP. These shares can only be used for grants to employees who were not employed or engaged by Pioneer or any of its subsidiaries immediately before the Parsley Acquisition and such awards may only be granted through May 22, 2024, the date that the 2014 Parsley Plan would have otherwise expired.

Stock-based compensation expense is as follows:


	Three Months Ended June 30,				Six Months Ended June 30,
	2021		2020		2021		2020

	(in millions)
Restricted stock - equity awards	$	10	$	10	$	21	$	22
Restricted stock - liability awards (a)	4		3		9		3
Restricted stock and performance units - Parsley awards (b)	—		—		33		—
Performance unit awards	6		6		14		10
Employee stock purchase plan	1		1		1		1

	$	21	$	20	$	78	$	36

______________________

(a)Liability Awards are expected to be settled on their vesting date in cash. As of June 30, 2021 and December 31, 2020, accounts payable – due to affiliates included $10 million and $7 million, respectively, of liabilities attributable to Liability Awards.

(b)Represents the accelerated vesting of Parsley restricted stock equity awards and performance units upon completion of the Parsley Acquisition, which was recorded to other expense in the consolidated statements of operations.

As of June 30, 2021, there was $91 million of unrecognized stock-based compensation expense related to unvested share-based compensation awards, including $18 million attributable to stock-based awards that are expected to be settled on their vesting date in cash, rather than in equity shares. The unrecognized compensation expense will be recognized on a straight-line basis over the remaining vesting periods of the awards, which is a period of less than three years on a weighted average basis.

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PIONEER NATURAL RESOURCES COMPANY

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

June 30, 2021

(Unaudited)

Activity for restricted stock awards, performance units and stock options is as follows:


	Six Months Ended June 30, 2021
	Restricted Stock Equity Awards	Restricted Stock Liability Awards	Performance Units	Stock Options
Beginning incentive compensation awards	765,981	221,353	207,430	86,332
Awards granted	127,370	3,085	173,423	—
Awards assumed (a) (c)	255,379	—	100,056	—
Awards forfeited	(4,049)	(4,227)	—	—
Awards vested (b) (c)	(417,749)	(42,761)	(100,056)	—
Options exercised	—	—	—	(55,173)
Options expired	—	—	—	(415)
Ending incentive compensation awards	726,932	177,450	380,853	30,744

______________________

(a)Awards assumed as a result of the Parsley Acquisition.

(b)Per the terms of award agreements and elections, the issuance of common stock may be deferred for certain restricted stock equity awards, performance units and stock options that vest during the period.

(c)The amounts presented include the assumption and accelerated vesting of 216,914 Parsley restricted stock equity awards and 100,056 of Parsley performance units, both of which vested upon completion of the Parsley Acquisition.

NOTE 9. Asset Retirement Obligations

The changes in asset retirement obligations are as follows:


	Six Months Ended June 30, 2021
	(in millions)
Beginning asset retirement obligations	$	282
Liabilities assumed in the Parsley Acquisition	73
Liabilities assumed in the DoublePoint Acquisition	37
New wells placed on production	5


Changes in estimates (a)	(1)




Liabilities settled	(15)
Accretion of discount	3



Ending asset retirement obligations	384

Less current portion of asset retirement obligations	(55)
Asset retirement obligations - noncurrent	$	329

______________________

(a)Changes in estimates are determined based on several factors, including updating abandonment cost estimates using recent actual costs incurred to abandon wells, credit-adjusted risk-free discount rates, economic well life estimates and forecasted timing of abandoning wells.

NOTE 10. Commitments and Contingencies

Legal actions. The Company is a party to various proceedings and claims incidental to its business. While many of these matters involve inherent uncertainty, the Company believes that the amount of the liability, if any, ultimately incurred with respect to these proceedings and claims will not have a material adverse effect on the Company's consolidated financial position as a whole or on its liquidity, capital resources or future annual results of operations. The Company records reserves for contingencies when information available indicates that a loss is probable and the amount of the loss can be reasonably estimated.

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PIONEER NATURAL RESOURCES COMPANY

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

June 30, 2021

(Unaudited)

Indemnifications. The Company has agreed to indemnify its directors and certain of its officers, employees and agents with respect to claims and damages arising from acts or omissions taken in such capacity, as well as with respect to certain litigation.

Environmental. Environmental expenditures that relate to an existing condition caused by past operations and that have no future economic benefits are expensed. Environmental expenditures that extend the life of the related property or mitigate or prevent future environmental contamination are capitalized. Liabilities for expenditures that will not qualify for capitalization are recorded when environmental assessment and/or remediation is probable and the costs can be reasonably estimated. Such liabilities are undiscounted unless the timing of cash payments for the liability is fixed or reliably determinable. Environmental liabilities normally involve estimates that are subject to revision until settlement or the remediation occurs.

Firm purchase, gathering, processing, transportation, fractionation and storage commitments. From time to time, the Company enters into, and as of June 30, 2021 was a party to, take-or-pay agreements, which include contractual commitments (i) to purchase sand, water and diesel for use in the Company's drilling and completion operations, (ii) with midstream service companies and pipeline carriers for future gathering, processing, transportation, fractionation and storage and (iii) with oilfield services companies that provide drilling and pressure pumping services. These commitments are normal and customary for the Company's business activities.

Obligations following divestitures. In connection with its divestiture transactions, the Company may retain certain liabilities and provide the purchaser certain indemnifications, subject to defined limitations, which may apply to identified pre-closing matters, including matters of litigation, environmental contingencies, royalties and income taxes. Also associated with its divestiture transactions, the Company has issued and received guarantees to facilitate the transfer of contractual obligations, such as firm transportation agreements or gathering and processing arrangements. The Company does not recognize a liability if the fair value of the obligation is immaterial and the likelihood of making payments under these guarantees is remote.

South Texas Divestiture. In conjunction with the 2019 divestiture of the Company's South Texas assets, the Company transferred its long-term midstream agreements and associated minimum volume commitments ("MVC's") to the buyer. However, the Company retained the obligation to pay 100 percent of any deficiency fees associated with the MVC's from January 2019 through July 2022. The buyer is required to reimburse the Company for 18 percent of the deficiency fees paid by the Company from January 2019 through July 2022; such reimbursement will be paid by the buyer in installments beginning in 2023 through 2025. Assuming 100 percent of the MVC's are paid as deficiency fees, the maximum amount of future payments for this obligation would be approximately $260 million as of June 30, 2021. The Company's estimated deficiency fee obligation as of June 30, 2021 is $199 million, of which $135 million is included in other current liabilities in the consolidated balance sheets. The deficiency fee receivable from the buyer of $77 million is included in noncurrent other assets in the consolidated balance sheets. The Company has credit support for the deficiency fee receivable of up to $100 million.

Raton transportation commitments. In July 2018, the Company completed the sale of its gas field assets in the Raton Basin to an unaffiliated third party and transferred certain gas transportation commitments, which extend through 2032, to the buyer for which the Company has provided a guarantee. Assuming 100 percent of the remaining commitments are paid by the Company under its guarantee, the maximum amount of future payments would be approximately $74 million as of June 30, 2021. The Company has received credit support for the commitments of up to $50 million. The Company paid $3 million in gas transportation fees associated with the transferred commitment for the six months ended June 30, 2021 and was fully reimbursed.

West Eagle Ford Shale commitments. In April 2018, the Company completed the sale of its West Eagle Ford Shale gas and liquids field to an unaffiliated third party and transferred certain gas and liquids transportation commitments, which extend through 2022, to the buyer for which the Company has provided a guarantee. Assuming 100 percent of the remaining commitments are paid by the Company under its guarantee, the maximum amount of future payments would be approximately $17 million as of June 30, 2021. The Company has received credit support for the commitments of up to $17 million.

Table of Contents

PIONEER NATURAL RESOURCES COMPANY

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

June 30, 2021

(Unaudited)

Certain contractual obligations were retained by the Company after the South Texas Divestiture, the Raton Basin asset sale, the divestiture of the Company's pressure pumping assets and the decommissioning of the Company's sand mine operations in Brady, Texas. These contracts were primarily related to firm transportation and storage agreements in which the Company is unlikely to realize any benefit. The estimated obligations are included in other current or noncurrent liabilities in the consolidated balance sheets. The changes in contract obligations are as follows:


	Six Months Ended June 30, 2021
	(in millions)
Beginning contract obligations	$	360

Liabilities settled	(152)
Accretion of discount	4
Changes in estimate (a)	(1)
Ending contract obligations	$	211

______________________

(a)Represents differences between estimated and actual liabilities settled.

NOTE 11. Related Party Transactions

In December 2018, the Company completed the sale of its pressure pumping assets to ProPetro in exchange for 16.6 million shares of ProPetro common stock and $110 million of cash that was received during the first quarter of 2019. ProPetro is considered a related party as the shares received represent 16 percent of ProPetro's outstanding common stock. In addition to the sale of equipment and related facilities, the Company entered into a long-term agreement with ProPetro for it to provide pressure pumping and related services. The costs of these services are capitalized in oil and gas properties as incurred.

In October 2019, Phillip A. Gobe, a nonemployee member of the Company's board of directors, was appointed by the board of directors of ProPetro to serve as its Executive Chairman, and in March 2020 he was appointed as Chief Executive Officer and Chairman of the Board of Directors. In July 2021, ProPetro announced that, effective August 31, 2021, Mr. Gobe would transition from ProPetro's Chairman and Chief Executive Officer to Executive Chairman. Mark S. Berg, the Company's Executive Vice President, Corporate Operations, serves as a member of the ProPetro board of directors under the Company's right to designate a director to the board of directors of ProPetro so long as the Company owns five percent or more of ProPetro's outstanding common stock.

Transactions and balances with ProPetro are as follows:


	Three Months Ended June 30,				Six Months Ended June 30,
	2021		2020		2021		2020

	(in millions)
Pressure pumping and related services charges (a)	$	111	$	76	$	167	$	143

____________________

(a)Includes $1 million and $5 million of idle frac fleet fees for the three and six months ended June 30, 2021, respectively, as compared to $30 million of idle frac fleet fees for both the three and six months ended June 30, 2020.


	As of June 30, 2021		As of December 31, 2020

	(in millions)

Accounts payable - due to affiliate (a)	$	78	$	45

____________________

(a)Represents pressure pumping and related services provided by ProPetro as part of a long-term agreement.

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PIONEER NATURAL RESOURCES COMPANY

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

June 30, 2021

(Unaudited)

The Company discloses ProPetro's summarized financial information on a one-quarter lag as it enables the Company to report its quarterly results independent from the timing of when ProPetro reports its results. Summarized financial information for ProPetro is as follows:


	Three Months Ended March 31,
	2021		2020

	(in millions)
Revenue - Service revenue	$	161	$	395
Cost of services (exclusive of depreciation and amortization)	$	123	$	301
Net loss	$	(20)	$	(8)

NOTE 12. Revenue Recognition

The Company recognizes revenue when control of the promised goods or services is transferred to customers at an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services.

Disaggregated revenue from contracts with purchasers. Revenues on sales of oil, NGLs, gas and purchased oil, gas and diesel are recognized when control of the product is transferred to the purchaser and payment can be reasonably assured. Sales prices for oil, NGLs, gas and diesel are negotiated based on factors normally considered in the industry, such as an index or spot price, distance from the well to the pipeline or market, commodity quality and prevailing supply and demand conditions. Accordingly, the prices received by the Company for oil, NGLs, gas and diesel sales generally fluctuate similar to changes in the relevant market index prices.

Disaggregated revenue from contracts with purchasers by product type is as follows:


	Three Months Ended June 30,				Six Months Ended June 30,
	2021		2020		2021		2020

	(in millions)
Oil sales	$	2,133	$	453	$	3,567	$	1,377
NGL sales	374		104		620		215
Gas sales	175		43		318		103
Total commodities sales	2,682		600		4,505		1,695
Sales of purchased oil	1,559		536		2,780		1,439
Sales of purchased gas	11		5		16		17
Sales of purchased diesel	17		—		32		—
Total sales of purchased commodities	1,587		541		2,828		1,456
Total revenue from contracts with purchasers	$	4,269	$	1,141	$	7,333	$	3,151

As of June 30, 2021 and December 31, 2020, the accounts receivable balance representing amounts due or billable under the terms of contracts with purchasers was $1.6 billion and $661 million, respectively.

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PIONEER NATURAL RESOURCES COMPANY

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

June 30, 2021

(Unaudited)

NOTE 13. Interest and Other Income (Loss), Net

The components of net interest and other income (loss) are as follows:


	Three Months Ended June 30,				Six Months Ended June 30,
	2021		2020		2021		2020

	(in millions)
Investment in affiliate fair value adjustment (Note 4)	$	(25)	$	44	$	29	$	(101)
Deferred compensation plan income (loss)	4		—		8		(3)



Contingent consideration fair value adjustment (Note 5)	—		(1)		—		(64)
Other	1		5		3		10
	$	(20)	$	48	$	40	$	(158)

NOTE 14. Other Expense

The components of other expense are as follows:


	Three Months Ended June 30,				Six Months Ended June 30,
	2021		2020		2021		2020

	(in millions)
Parsley Acquisition transaction costs (a)	$	9	$	—	$	206	$	—
Winter Storm Uri gas commitments (b)	—		—		80		—
DoublePoint Acquisition transaction costs (c)	27		—		27		—
Unoccupied facility expense (d)	7		(1)		17		(1)
Transportation commitment charges (e)	3		5		10		8
Termination and idle drilling and frac equipment charges (f)	1		44		5		53
Loss (gain) on early extinguishment of debt (Note 7)	(3)		27		2		27



South Texas deficiency fee obligation (Note 4)	—		—		—		69


Vertical integration services loss (income), net (g)	(1)		5		(5)		1

Other	4		10		9		18
	$	47	$	90	$	351	$	175

____________________

(a)Represents costs associated with the Parsley Acquisition, which includes $90 million of employee-related costs and $116 million of transaction-related fees during the six months ended June 30, 2021 and $9 million of transaction-related fees during the three months ended June 30, 2021.

(b)Represents costs related to the Company's fulfillment of certain firm gas commitments during Winter Storm Uri in February 2021.

(c)Represents transaction costs associated with the DoublePoint Acquisition.

(d)Primarily facilities expense associated with certain acquired Parsley offices that are no longer occupied.

(e)Primarily represents firm transportation payments on excess pipeline capacity commitments.

(f)Includes idle frac fleet fees, stacked drilling rig charges and drilling rig early termination charges.

(g)Primarily represents net margins (attributable to third party working interest owners) that result from Company-provided vertically integrated services, which are ancillary to and supportive of the Company's oil and gas joint operating activities, and do not represent intercompany transactions. The components of the vertical integration services net margins are as follows:

Table of Contents

PIONEER NATURAL RESOURCES COMPANY

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

June 30, 2021

(Unaudited)


	Three Months Ended June 30,				Six Months Ended June 30,
	2021		2020		2021		2020

	(in millions)
Gross revenues	$	11	$	14	$	23	$	25
Gross costs and expenses	$	10	$	19	$	18	$	26

NOTE 15. Income Taxes

Income tax benefit (provision) and effective tax rate are as follows:


	Three Months Ended June 30,						Six Months Ended June 30,
	2021			2020			2021			2020

	(in millions)
Current tax benefit (provision)	$	(11)		$	11		$	(18)		$	11
Deferred tax benefit (provision)	(109)			98			(91)			20
Income tax benefit (provision)	$	(120)		$	109		$	(109)		$	31
Effective tax rate	24		%	20		%	26		%	17		%

The Company evaluates and updates its annual effective income tax rate on an interim basis based on current and forecasted earnings and tax laws. The mix and timing of the Company's actual earnings compared to annual projections can cause interim effective tax rate fluctuations. The Company's interim effective tax rate for the three and six months ended June 30, 2021 differed from the U.S. statutory rate of 21 percent primarily due to forecasted state income taxes.

The Company files income tax returns in the U.S. federal and various state and foreign jurisdictions. The Internal Revenue Service has closed examinations of the 2018 and prior tax years and, with few exceptions, the Company believes that it is no longer subject to examinations by state and foreign tax authorities for years before 2012. As of June 30, 2021, no adjustments had been proposed in any jurisdiction that would have a significant effect on the Company's liquidity, future results of operations or financial position.

DoublePoint Acquisition. The Company purchased all the membership interests of DoublePoint, a disregarded entity for federal income tax purposes. As a result, for tax purposes, the Company recorded the cost basis in the assets acquired equal to its purchase price (i.e. stepped-up basis).

Parsley Acquisition. For federal income tax purposes, the Parsley Acquisition qualified as a tax-free merger whereby the Company acquired carryover tax basis in Parsley's assets and liabilities. The Company recorded a deferred tax liability of $127 million associated with the acquired assets. Included in the deferred tax liability are deferred tax asset attributes acquired from Parsley, which primarily consist of net operating loss carryforwards of $2 billion that are subject to an annual limitation under Internal Revenue Code Section 382. The Company believes it is more likely than not that the acquired net operating loss carryforwards will be utilized before they expire. Offsetting the deferred tax assets attributes are deferred tax liability attributes, primarily related to the cost basis in oil and gas properties for tax purposes being less than the recorded book amounts.

Enactment of the Consolidated Appropriations Act, 2021. On December 27, 2020, President Trump signed into law the Consolidated Appropriations Act, 2021 (the "Act"). The Act includes many tax provisions, including the extension of various expiring provisions and extensions and expansions of certain pandemic tax relief provisions, among other things. The Act did not have a material impact on the Company's current or prior year tax provision or the Company's consolidated financial statements.

Enactment of the Coronavirus Aid, Relief and Economic Security Act. On March 27, 2020, President Trump signed into law the Coronavirus Aid, Relief and Economic Security Act ("CARES Act"). The CARES Act, among other things, includes provisions relating to refundable payroll tax credits, deferment of employer social security payments, net operating loss carryback periods, alternative minimum tax credit refunds, modifications to the net interest deduction limitations and technical corrections to tax depreciation methods for qualified improvement property. The CARES Act did not have a material impact on the Company's current or prior year tax provision or the Company's consolidated financial statements.

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PIONEER NATURAL RESOURCES COMPANY

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

June 30, 2021

(Unaudited)

NOTE 16. Net Income (Loss) Per Share

The components of basic and diluted net income (loss) per share attributable to common stockholders are as follows:


	Three Months Ended June 30,				Six Months Ended June 30,
	2021		2020		2021		2020

	(in millions)
Net income (loss) attributable to common stockholders	$	380	$	(449)	$	310	$	(158)
Participating share-based earnings (a)	(1)		—		(1)		—
Basic net income (loss) attributable to common stockholders	379		(449)		309		(158)



Adjustment to after-tax interest expense to reflect the dilutive impact attributable to the Convertible Notes	1		—		3		—
Diluted net income (loss) attributable to common stockholders	$	380	$	(449)	$	312	$	(158)

Basic weighted average shares outstanding	234		165		222		165
Contingently issuable stock-based compensation	1		—		1		—
Convertible Notes dilution (b)	12		—		12		—
Diluted weighted average shares outstanding	247		165		235		165

____________________

(a)Unvested restricted stock awards represent participating securities because they participate in non-forfeitable dividends with the common equity owners of the Company. Participating share based earnings represent the distributed and undistributed earnings of the Company attributable to the participating securities. Unvested restricted stock awards do not participate in undistributed net losses as they are not contractually obligated to do so. The dilutive effect of the reallocation of participating share-based earnings to diluted net income (loss) attributable to common stock holders was negligible.

(b)Diluted weighted average common shares outstanding have been increased to reflect the dilutive effect that would have resulted if the Company's Convertible Notes had been converted at the beginning of the three and six months ended June 30, 2021. If converted by the holder, the Company intends to settle the Convertible Notes in cash.

Stock repurchase program. In December 2018, the Company's board of directors authorized a $2 billion common stock repurchase program. Under this stock repurchase program, the Company may repurchase shares at management's discretion in accordance with applicable securities laws. In addition, the Company may repurchase shares pursuant to a trading plan meeting the requirements of Rule 10b5-1 under the Securities Act of 1934, which would permit the Company to repurchase shares at times that may otherwise be prohibited under the Company's insider trading policy. The stock repurchase program has no time limit and may be modified, suspended or terminated at any time by the board of directors.

Expenditures to acquire shares under the share repurchase program are as follows:


	Three Months Ended June 30,				Six Months Ended June 30,
	2021		2020		2021		2020

	(in millions)
Share repurchases (a)	$	—	$	50	$	—	$	160

____________________

(a)During the three and six months ended June 30, 2021, no shares were repurchased under the share repurchase program, as compared to 592,136 and 1,511,930 shares repurchased for the same respective periods in 2020.

As of June 30, 2021, $1.1 billion remains available for use to repurchase shares under the Company's common stock repurchase program.

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PIONEER NATURAL RESOURCES COMPANY

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

June 30, 2021

(Unaudited)

NOTE 17. Subsequent Events

Variable Dividend. In August 2021, the board of directors declared a cash dividend of $1.51 per share on the Company's outstanding common stock, payable September 17, 2021 to stockholders of record at the close of business on September 3, 2021.

PIONEER NATURAL RESOURCES COMPANY


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

Parsley Acquisition and DoublePoint Acquisition

The Company regularly seeks to acquire or trade acreage that complements its operations, provides exploration and development opportunities, increases the lateral length of future horizontal wells and provides superior returns on investment (including opportunities to acquire particular oil and gas assets or entities owning oil and gas assets and opportunities to engage in mergers, consolidations or other business combinations with such entities).

On May 4, 2021, the Company completed the acquisition of Double Eagle III Midco 1 LLC ("DoublePoint") in exchange for 27 million shares of Pioneer common stock representing stock consideration transferred of $4 billion, $1 billion of cash and the assumption of $890 million of debt (the "DoublePoint Acquisition"). The DoublePoint Acquisition was accounted for as a business combination, with the fair value of the acquisition consideration allocated to the acquisition date fair value of assets acquired and liabilities assumed. DoublePoint's results of operations were included in the Company's interim consolidated financial statements beginning in May 2021. See Note 3 of Notes to Consolidated Financial Statements included in "Item 1. Financial Statements" for additional information.

The Company completed the acquisition of Parsley Energy, Inc., a Delaware corporation that previously traded on the NYSE under the symbol "PE" ("Parsley"), pursuant to the Agreement and Plan of Merger, dated as of October 20, 2020, among Pioneer, certain of its subsidiaries, Parsley and Parsley's subsidiary, Parsley Energy, LLC (the "Parsley Acquisition") on January 12, 2021. The Parsley Acquisition was accounted for as a business combination, with the fair value of the acquisition consideration allocated to the acquisition date fair value of assets acquired and liabilities assumed. Parsley's post-acquisition date results of operations were included in the Company's interim consolidated financial statements beginning on January 12, 2021. See Note 3 of Notes to Consolidated Financial Statements included in "Item 1. Financial Statements" for additional information.

Financial and Operating Performance

The Company's financial and operating performance for the three months ended June 30, 2021 included the following highlights:

•Net income attributable to common stockholders for the three months ended June 30, 2021 was $380 million ($1.54 per diluted share) as compared to net loss of $449 million ($2.73 per diluted share) for the same period in 2020. The primary components of the $829 million increase in earnings attributable to common stockholders include:

•a $2.1 billion increase in oil and gas revenues due to a 166 percent increase in average realized commodity prices per BOE as a result of improved commodity prices due to the economic recovery from the COVID-19 pandemic and a 68 percent increase in daily sales volumes due to additional production from the Company's successful horizontal drilling program in the Permian Basin, the Parsley Acquisition and the DoublePoint Acquisition; and

•a $43 million decrease in other expense, primarily due to (i) a $43 million decrease in idle frac fleet fees, stacked drilling rig charges and drilling rig early termination charges and (ii) a $3 million gain on early extinguishment of debt for the three months ended June 30, 2021, as compared to a $27 million loss on early extinguishment of debt for the same period in 2020, partially offset by $36 million of transaction-related costs associated with the Parsley Acquisition and DoublePoint Acquisition;

partially offset by:

•a $476 million decrease in net derivative results, primarily due to changes in forward commodity prices and the cash settlement of derivative positions in accordance with their terms;

•a $255 million increase in production costs, including taxes, primarily attributable to (i) an increase in production taxes as a result of the aforementioned 166 percent increase in average realized commodity prices and (ii) increased costs attributable to production added from the Parsley Acquisition and the DoublePoint Acquisition;

•a $232 million increase in DD&A expense, primarily due to an increase in sales volumes from the Company's successful horizontal drilling program in the Permian Basin, the Parsley Acquisition and the DoublePoint Acquisition;

•a $229 million increase in the Company's income tax provision due to the increase in earnings during the three months ended June 30, 2021 as compared to the same period in 2020; and

PIONEER NATURAL RESOURCES COMPANY

•a $68 million decrease in net interest and other income (loss), primarily due to a noncash loss of $25 million attributable to the decrease in the fair value of the Company's investment in affiliate during the three months ended June 30, 2021 as compared to a noncash gain of $44 million for the same period in 2020.

•During the three months ended June 30, 2021, average daily sales volumes increased by 68 percent to 629,468 BOEPD, as compared to 374,563 BOEPD during the same period in 2020, due to additional production from Company's successful horizontal drilling program in the Permian Basin, the Parsley Acquisition and the DoublePoint Acquisition.

•Average oil and NGL prices per Bbl and average gas prices per Mcf increased to $64.55, $27.95 and $2.69, respectively, during the three months ended June 30, 2021 as compared to $23.16, $12.65 and $1.15, respectively, for the same period in 2020.

•Cash provided by operating activities increased during the three months ended June 30, 2021 to $1.5 billion as compared to $328 million for the same period in 2020. The increase was primarily due to an increase in oil and gas revenues due to the aforementioned increase in commodity prices and sales volumes partially offset by (i) additional cash used in derivative activities and (ii) an increase in production costs due to the aforementioned increase in production taxes attributable to the increase in commodity prices and costs attributable to the production added from the Parsley Acquisition and the DoublePoint Acquisition.

•As of June 30, 2021 and December 31, 2020, the Company's net debt to book capitalization was 23 percent and 14 percent, respectively.

Impact of the COVID-19 Pandemic

The COVID-19 pandemic resulted in a severe worldwide economic downturn, significantly disrupting the demand for oil throughout the world, and created significant volatility, uncertainty and turmoil in the oil and gas industry. The decrease in demand for oil combined with pressures on the global supply-demand balance for oil and related products, resulted in oil prices declining significantly beginning in late February 2020. Although demand has shown signs of recovery, there is significant uncertainty regarding the long-term impact to global oil demand, which will ultimately depend on various factors and consequences beyond the Company's control, such as the duration and scope of the pandemic, the length and severity of the worldwide economic downturn, the ability of OPEC, Russia and other oil producing nations to manage the global oil supply, additional actions by businesses and governments in response to the pandemic, the economic downturn and the decrease in oil demand, the speed and effectiveness of responses to combat the virus, and the time necessary to balance oil supply and demand to restore oil pricing.

The Company continues to assess the global impacts of the COVID-19 pandemic and may modify its plans as the economic and health impacts of COVID-19 continue to evolve.

Third Quarter 2021 Outlook

The Company's operating and financial results for the third quarter of 2021 and beyond are uncertain and will depend on various factors beyond the Company's control, such as: the duration of the COVID-19 pandemic and the speed and effectiveness of vaccine distributions to combat the virus; environmental and trade policies; fiscal challenges facing the United States federal government; geopolitical issues globally, especially in the Middle East; the extent to which OPEC members and some nonmembers, including Russia, adhere to and agree to extend cuts to their oil production quotas; the timing and supply impact of any Iranian sanction relief on Iran's ability to export oil and the uncertainty in oil demand fundamentals associated with governmental policy aimed at redirecting fossil fuel consumption towards lower carbon energy.

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PIONEER NATURAL RESOURCES COMPANY

Based on current estimates, the Company expects the following operating and financial results for the third quarter of 2021:


			Three Months Ending September 30, 2021
			Guidance
			($ in millions, except per BOE amounts)
Average daily production (MBOE)			660 - 685
Average daily oil production (MBO)			380 - 395
Production costs per BOE			$7.25 - $8.75
DD&A per BOE			$10.75 - $12.75
Exploration and abandonments expense			$10 - $20
General and administrative expense			$67 - $77
Accretion of discount on asset retirement obligations			$2 - $5
Interest expense			$39 - $44
Other expense			$15 - $30
Cash flow impact from firm transportation (a)			$(65) - $(35)
Current income tax provision			$5 - $15
Effective tax rate			22% - 27%

______________________

(a)The cash flow impact from firm transportation is primarily based on the forecasted differential between WTI oil prices and Brent oil prices less the costs to transport purchased oil from the areas of the Company's production to the Gulf Coast. To the extent that the Company's Gulf Coast sales of purchased oil does not cover the purchase price and associated firm transport costs, the Company's results of operations will reflect the negative cashflow impact attributable to its firm transportation commitments. The cash flow impact from firm transportation does not include the expected cash flow impact from the Company's firm transportation marketing contracts that are accounted for as derivatives.

Operations and Drilling Highlights

Average daily oil, NGL and gas sales volumes are as follows:


						Six Months Ended June 30, 2021

Oil (Bbls)						322,258
NGL (Bbls)						126,520
Gas (Mcf)						620,124
Total (BOE)						552,132

The Company's liquids production was 81 percent of total production, on a BOE basis, for the six months ended June 30, 2021.

Costs incurred are as follows:


	Six Months Ended June 30, 2021
	(in millions)
Proved property acquisition costs (a)	$	9,039


Unproved property acquisitions (a)	8,054
Exploration/extension costs	1,173
Development costs	316
Asset retirement obligations	5
	$	18,587

_____________________

(a)Includes proved and unproved acquisition costs related to the Parsley Acquisition of $5.1 billion and $5.6 billion, respectively, and proved and unproved acquisition costs related to the DoublePoint Acquisition of $3.9 billion and $2.4 billion, respectively.

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PIONEER NATURAL RESOURCES COMPANY

Development and exploration/extension drilling activity is as follows:


	Six Months Ended June 30, 2021
	Development	Exploration/Extension


Beginning wells in progress	9	210
Wells spud	11	227
Acquired wells in progress	4	103


Successful wells	(11)	(252)

Ending wells in progress	13	288

The Company is currently operating 24 drilling rigs and eight frac fleets in the Midland Basin. The Company plans to move four drilling rigs to the Delaware Basin during the third quarter of 2021. The Company will continue to evaluate its drilling and completions program with future activity levels assessed regularly.

During the six months ended June 30, 2021, the Company successfully completed 198 horizontal wells in the northern portion of the Midland Basin, 48 horizontal wells in the southern portion of the Midland Basin and 17 horizontal wells in the Delaware Basin. In the northern portion of the Midland Basin, 42 percent of the horizontal wells placed on production were Wolfcamp A interval wells, 30 percent were Wolfcamp B interval wells and the remaining 28 percent were primarily Spraberry and Wolfcamp D interval wells. In the southern portion of the Midland Basin, the majority of the wells placed on production were Wolfcamp A and B interval wells. In the Delaware Basin, approximately 35 percent were in the Bone Spring interval and the remaining 65 percent were Wolfcamp A and B interval wells.

Results of Operations

Oil and gas revenues.

Average daily sales volumes are as follows:


	Three Months Ended June 30,				Six Months Ended June 30,
	2021	2020	% Change		2021	2020	% Change
Oil (Bbls)	363,046	214,959	69	%	322,258	218,808	47	%
NGL (Bbls)	147,135	90,184	63	%	126,520	87,271	45	%
Gas (Mcf)	715,719	416,516	72	%	620,124	412,704	50	%
Total (BOEs)	629,468	374,563	68	%	552,132	374,863	47	%

The increase in average daily BOE sales volumes for the three and six months ended June 30, 2021, as compared to the same periods in 2020 was due to the Company's successful Spraberry/Wolfcamp horizontal drilling program, combined with the production added from the Parsley Acquisition and the DoublePoint Acquisition.

The oil, NGL and gas prices that the Company reports are based on the market prices received for each commodity. Commodity prices for the three and six months ended June 30, 2021, as compared to the same respective periods in 2020, increased due to the continued recovery in oil, NGL and gas demand from the COVID-19 pandemic. The average prices are as follows:


	Three Months Ended June 30,						Six Months Ended June 30,
	2021		2020		% Change		2021		2020		% Change
Oil per Bbl	$	64.55	$	23.16	179	%	$	61.15	$	34.58	77	%
NGL per Bbl	$	27.95	$	12.65	121	%	$	27.10	$	13.55	100	%
Gas per Mcf	$	2.69	$	1.15	134	%	$	2.83	$	1.38	105	%
Total per BOE	$	46.82	$	17.61	166	%	$	45.08	$	24.85	81	%

Purchased commodities. The Company enters into pipeline capacity commitments in order to secure available oil, NGLs and gas transportation capacity from the Company's areas of production and secure diesel supply from the Gulf Coast to the Company's operations in the Permian Basin. The Company enters into purchase transactions with third parties and separate sale transactions with third parties to diversify a portion of the Company's oil and gas sales to (i) Gulf Coast refineries, (ii) Gulf Coast and West Coast gas markets and (iii) international oil markets, and to satisfy unused gas pipeline capacity commitments.

Revenues and expenses from these transactions are generally presented on a gross basis in sales of purchased commodities and purchased commodities in the accompanying consolidated statements of operations as the Company acts as a principal in the transaction by assuming both the risks and rewards of ownership, including credit risk, of the commodities

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PIONEER NATURAL RESOURCES COMPANY

purchased and the responsibility to deliver the commodities sold. The Company has also entered into long-term marketing contracts, which are accounted for as derivatives, to similarly diversify its oil sales to Gulf Coast and international markets. The marketing contracts were entered in October 2019, each with a January 1, 2021 contract commencement date and a December 31, 2026 contract termination date. The gains and losses associated with the Company's marketing derivatives are recognized in net derivative gains (losses) in the consolidated statements of operations. In conjunction with the Company's downstream sales, the Company also enters into pipeline capacity commitments in order to secure available oil, NGL and gas transportation capacity from the Company's areas of production to downstream sales points. The transportation costs associated with sales of purchased commodities are included in purchased commodities expense. See Consolidated Statements of Operations included in "Item 1. Financial Statements" for additional information.

The net effects of third party purchases and sales of commodities and associated marketing contracts are as follows:


	Three Months Ended June 30,						Six Months Ended June 30,
	2021		2020		Change		2021		2020		Change

	(in millions)
Sales of purchased commodities	$	1,587	$	541	$	1,046	$	2,828	$	1,456	$	1,372
Purchased commodities	1,627		572		1,055		2,882		1,600		1,282
Net effect	(40)		(31)		(9)		(54)		(144)		90
Realized marketing derivative loss	(13)		—		(13)		(20)		—		(20)
	$	(53)	$	(31)	$	(22)	$	(74)	$	(144)	$	70

The change in net sales of purchased commodities for the three months ended June 30, 2021, as compared to the same period in 2020, was primarily due to a decrease in 2021 downstream oil margins on the Company's Gulf Coast refinery and export sales. The change in net sales of purchased commodities for the six months ended June 30, 2021, as compared to the same period in 2020, was primarily due to a $74 million loss during the first quarter of 2020 attributable to oil that was purchased and in transit via pipeline to the Gulf Coast or in Gulf Coast storage at the end of January and February, which was subsequently sold in February 2020 and March 2020, respectively, at lower prices. This oil inventory is sold in the month following purchase at contracted prices that are generally tied to monthly average index oil prices (typically Brent oil prices).

The realized losses associated with the commencement of the marketing derivative contracts in 2021 were due to differences in the oil volumes purchased by the Company which were based on Midland WTI prices and sold at prices highly correlated to Brent pricing. See Note 5 of Notes to Consolidated Financial Statements included in "Item 1. Financial Statements" for additional information.

Firm transportation payments on excess pipeline capacity are included in other expense in the accompanying consolidated statements of operations. See Note 14 of Notes to Consolidated Financial Statements included in "Item 1. Financial Statements" for additional information.

Interest and other income (loss), net.


	Three Months Ended June 30,						Six Months Ended June 30,
	2021		2020		Change		2021		2020		Change

	(in millions)
Interest and other income (loss), net	$	(20)	$	48	$	(68)	$	40	$	(158)	$	198

The decrease in net interest and other income (loss) for the three months ended June 30, 2021, as compared to the same period in 2020, was primarily due to a noncash loss of $25 million attributable to the change in fair value of the Company's investment in affiliate in 2021 compared to a noncash gain of $44 million in 2020. The increase in net interest and other income (loss) for the six months ended June 30, 2021, as compared to the same period in 2020, was primarily due to (i) a noncash gain of $29 million attributable to the change in fair value of the Company's investment in affiliate in 2021 compared to a noncash loss of $101 million in 2020 and (ii) a $64 million noncash loss attributable to the decrease in fair value of contingent consideration associated with the South Texas Divestiture.

See Note 13 of Notes to Consolidated Financial Statements included in "Item 1. Financial Statements" for additional information.

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PIONEER NATURAL RESOURCES COMPANY

Derivative gain (loss), net.


	Three Months Ended June 30,						Six Months Ended June 30,
	2021		2020		Change		2021		2020		Change

	(in millions)
Commodity derivatives:



Noncash derivative loss, net	$	(279)	$	(463)	$	184	$	(629)	$	(54)	$	(575)




Cash receipts (payments) on settled derivative instruments, net	(557)		128		(685)		(871)		191		(1,062)
Total commodity derivative gain (loss), net	(836)		(335)		(501)		(1,500)		137		(1,637)

Marketing derivatives:
Noncash derivative gain (loss), net	17		(21)		38		(3)		(15)		12


Cash payments on settled derivative instruments, net	(13)		—		(13)		(20)		—		(20)
Total marketing derivative gain (loss), net	4		(21)		25		(23)		(15)		(8)

Interest rate derivatives:
Cash payments on settled derivative instruments, net	—		—		—		—		(22)		22


Derivative gain (loss), net	$	(832)	$	(356)	$	(476)	$	(1,523)	$	100	$	(1,623)

The Company primarily utilizes commodity swap contracts, collar contracts, collar contracts with short puts and basis swap contracts to (i) reduce the effect of price volatility on the commodities the Company produces and sells or consumes, (ii) support the Company's capital budgeting and expenditure plans and (iii) support the payment of contractual obligations and dividends. The Company uses marketing derivatives to diversify its oil sales to Gulf Coast and international markets. The Company also, from time to time, utilizes interest rate contracts to reduce the effect of interest rate volatility on the Company's indebtedness.

Commodity derivative settlements and the related price impact (per Bbl or Mcf) are as follows:


	Three Months Ended June 30, 2021					Six Months Ended June 30, 2021

	Net cash payments		Price impact			Net cash payments		Price impact
	(in millions)					(in millions)


Oil derivative payments (a)	$	(548)	$	(16.60)	per Bbl	$	(841)	$	(14.42)	per Bbl



Gas derivative payments	(9)		$	(0.13)	per Mcf	(17)		$	(0.14)	per Mcf
Total net commodity derivative payments	$	(557)				$	(858)

_____________________

(a)Excludes the effect of liquidating certain of the Company's 2022 WTI swap contracts for cash payments of $13 million during the six months ended June 30, 2021.


	Three Months Ended June 30, 2020					Six Months Ended June 30, 2020
	Net cash receipts		Price impact			Net cash receipts		Price impact
	(in millions)					(in millions)
Oil derivative receipts (a)	$	96	$	4.91	per Bbl	$	159	$	4.00	per Bbl

_____________________

(a)Excludes the effect of liquidating certain of the Company's Brent collar contracts with short puts and Brent swap contracts for cash receipts of $32 million for the three and six months ended June 30, 2020.

The Company's open derivative contracts are subject to continuing market risk. See "Item 3. Quantitative and Qualitative Disclosures About Market Risk" and Note 4 and Note 5 of Notes to Consolidated Financial Statements included in "Item 1. Financial Statements" for additional information.

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PIONEER NATURAL RESOURCES COMPANY

Gain on disposition of assets, net


	Three Months Ended June 30,						Six Months Ended June 30,
	2021		2020		Change		2021		2020		Change
	(in millions)
Gain on disposition of assets, net	$	2	$	6	$	(4)	$	13	$	6	$	7

The decrease in gain on disposition of assets for the three months ended June 30, 2021, as compared to the same period in 2020, was primarily due to the Company recognizing a $6 million gain on the sale of certain vertical wells and approximately 1,500 net acres in 2020. The increase in gain on disposition of assets for the six months ended June 30, 2021, as compared to the same period in 2020, was primarily due to recognizing a gain of $9 million in 2021 associated with the sale of the Company's well services business to a third party for net cash proceeds of $20 million. See Note 3 of Notes to Consolidated Financial Statements included in "Item 1. Financial Statements" for additional information.

Oil and gas production costs.


	Three Months Ended June 30,						Six Months Ended June 30,
	2021		2020		Change		2021		2020		Change

	(in millions)
Oil and gas production costs	$	316	$	167	$	149	$	568	$	343	$	225

Oil and gas production costs per BOE are as follows:


	Three Months Ended June 30,						Six Months Ended June 30,
	2021		2020		% Change		2021		2020		% Change
Lease operating expense per BOE (a)	$	3.05	$	2.78	10	%	$	3.23	$	3.05	6	%
Gathering, processing and transportation expense per BOE (b)	2.66		2.38		12	%	2.83		2.45		16	%
Workover costs per BOE (a)	0.39		0.10		290	%	0.40		0.27		48	%
Net natural gas plant income per BOE (c)	(0.59)		(0.34)		74	%	(0.79)		(0.74)		7	%
	$	5.51	$	4.92	12	%	$	5.67	$	5.03	13	%

_____________________

(a)Lease operating expense and workover expense represent the components of oil and gas production costs over which the Company has management control.

(b)Gathering, processing and transportation expense represents the costs to gather, process, transport and fractionate the Company's gas and NGLs to a point of sale.

(c)Net natural gas plant income represents the earnings from the Company's ownership share of gas processing facilities that gather and process the Company's and third party gas.

Although the Company continues to realize the benefit of lower production costs in 2021 due to the Company's cost saving initiatives, the Company realized higher than expected production costs during the three and six months ended June 30, 2021 compared to the same periods in 2020 due to the following:

•Lease operating expense per BOE increased for the three months ended June 30, 2021, as compared to the same period in 2020, due to higher cost Delaware Basin assets acquired in the Parsley Acquisition. Lease operating expense per BOE increased for the six months ended June 30, 2021, as compared to the same period in 2020 primarily due to (i) higher cost Delaware Basin assets acquired in the Parsley Acquisition and (ii) an increase in electricity costs and lower production associated with the impact Winter Storm Uri had on the Company's operations in February 2021;

•Gathering, processing and transportation expense per BOE increased for the three months ended June 30, 2021, as compared to the same period in 2020 primarily due to (i) transportation costs related to new pipeline takeaway capacity for the Company's gas and NGL production and (ii) increased gas and NGL prices during the second quarter of 2021 that resulted in increased gas processing costs for those contractual volumes retained by the processor as payment for their services. Gathering, processing and transportation expense per BOE increased for the six months ended June 30, 2021, as compared to the same period in 2020 primarily due to (i) transportation costs related to new pipeline takeaway capacity for the Company's gas and NGL production, (ii) increased gas processing and transportation costs as a result of higher electricity costs during Winter Storm Uri in February 2021

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and (iii) increased gas and NGL prices during 2021 that resulted in increased gas processing costs for those contractual volumes retained by the processor as payment for their services;

•Workover costs per BOE increased for the three and six months ended June 30, 2021, as compared to the same periods in 2020, due to an increase in workover activity as a result of improved commodity prices being realized in 2021, which increased the economic benefit of repairing certain of the Company's oil and gas wells; and

•Net natural gas plant income per BOE increased for the three months ended June 30, 2021, as compared to the same period in 2020 primarily due to improved gas and NGL prices. Net natural gas plant income per BOE increased for the six months ended June 30, 2021, as compared to the same period in 2020 primarily due to improved gas and NGL prices, partially offset by a temporary decrease in volumes processed as a result of Winter Storm Uri's impact to the Company's processing facilities.

Production and ad valorem taxes.


	Three Months Ended June 30,						Six Months Ended June 30,
	2021		2020		Change		2021		2020		Change

	(in millions)
Production and ad valorem taxes	$	153	$	47	$	106	$	266	$	120	$	146

In general, production taxes and ad valorem taxes are directly related to commodity price changes; however, Texas ad valorem taxes are based upon prior year commodity prices, whereas production taxes are based upon current year commodity prices.

Production and ad valorem taxes per BOE are as follows:


	Three Months Ended June 30,						Six Months Ended June 30,
	2021		2020		% Change		2021		2020		% Change
Production taxes per BOE	$	2.15	$	0.70	207	%	$	2.07	$	1.07	93	%
Ad valorem taxes per BOE	0.52		0.65		(20	%)	0.58		0.69		(16	%)
	$	2.67	$	1.35	98	%	$	2.65	$	1.76	51	%

The increase in production taxes per BOE for the three and six months ended June 30, 2021, as compared to the same periods in 2020, was primarily due to increases in oil, NGL and gas commodity prices. The decrease in ad valorem taxes per BOE for the three and six months ended June 30, 2021, as compared to the same periods in 2020, was primarily due to lower prior year commodity prices that are used to determine current year ad valorem taxes.

Depletion, depreciation and amortization expense.


	Three Months Ended June 30,						Six Months Ended June 30,
	2021		2020		Change		2021		2020		Change

	(in millions)
Depletion, depreciation and amortization	$	648	$	416	$	232	$	1,121	$	850	$	271

Total DD&A and depletion expense per BOE is as follows:


	Three Months Ended June 30,						Six Months Ended June 30,
	2021		2020		% Change		2021		2020		% Change
DD&A per BOE	$	11.31	$	12.21	(7	%)	$	11.22	$	12.46	(10	%)
Depletion expense per BOE	$	11.04	$	11.57	(5	%)	$	10.83	$	11.83	(8	%)

The decrease in DD&A per BOE and depletion expense per BOE was primarily due to incremental additions to proved reserves attributable to (i) new wells placed on production from the Company's successful Spraberry/Wolfcamp horizontal drilling program and (ii) improved commodity prices (which has the effect of extending the economic life of producing wells). In addition, the DD&A per BOE and depletion expense per BOE attributable to the Parsley Acquisition and the DoublePoint Acquisition were lower than the Company's respective 2020 per BOE amounts.

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Exploration and abandonments expense. Geological and geophysical costs and lease abandonments and other exploration expenses are as follows:


	Three Months Ended June 30,						Six Months Ended June 30,
	2021		2020		Change		2021		2020		Change

	(in millions)
Geological and geophysical	$	10	$	9	$	1	$	26	$	16	$	10

Leasehold abandonments and other	—		1		(1)		3		3		—
	$	10	$	10	$	—	$	29	$	19	$	10

The increase in geological and geophysical costs for the six months ended June 30, 2021, as compared to the same period in 2020, was primarily due to relicensing certain seismic data in connection with the Parsley Acquisition.

During the six months ended June 30, 2021, the Company drilled and evaluated 252 exploration/extension wells, of which 100 percent were successfully completed as discoveries. During the same period in 2020, the Company drilled and evaluated 156 exploration/extension wells, of which 100 percent were successfully completed as discoveries.

General and administrative expense.


	Three Months Ended June 30,						Six Months Ended June 30,
	2021		2020		Change		2021		2020		Change

	(in millions)
Noncash general and administrative expense	$	12	$	10	$	2	$	24	$	15	$	9
Cash general and administrative expense	63		50		13		119		101		18
	$	75	$	60	$	15	$	143	$	116	$	27

The change in noncash general and administrative expense for the three and six months ended June 30, 2021, as compared to the same periods in 2020, is primarily due to market fluctuations in the Company's deferred compensation obligation as a result of mark-to-market valuation changes attributable to the Company's deferred compensation plan assets.

The change in cash general and administrative expense for the three and six months ended June 30, 2021, as compared to the same periods in 2020, was primarily due to the reinstatement of certain employee benefits during 2021 that were temporarily suspended during 2020 in response to the COVID-19 pandemic.

Total general and administrative expense per BOE is as follows:


	Three Months Ended June 30,						Six Months Ended June 30,
	2021		2020		% Change		2021		2020		% Change



Noncash general and administrative expense per BOE	$	0.21	$	0.29	(28	%)	$	0.24	$	0.22	9	%
Cash general and administrative expense per BOE	1.10		1.46		(25	%)	1.19		1.48		(20	%)
	$	1.31	$	1.75	(25	%)	$	1.43	$	1.70	(16	%)

The decrease in general and administrative expense per BOE for the three and six months ended June 30, 2021, reflect the general and administrative synergies achieved from the Parsley Acquisition beginning in January 2021 and the DoublePoint Acquisition beginning in May 2021. The Company added the production volumes from the acquisitions, with limited associated general and administrative costs.

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Interest expense.


	Three Months Ended June 30,						Six Months Ended June 30,
	2021		2020		Change		2021		2020		Change

	(in millions)


Noncash interest expense	$	7	$	13	$	(6)	$	12	$	18	$	(6)


Cash interest expense	34		20		14		69		42		27
	$	41	$	33	$	8	$	81	$	60	$	21

The Company early adopted Accounting Standard Update ("ASU") 2020-06 effective January 1, 2021, as a result of this early adoption, the Company reversed the debt discount recorded to additional paid-in capital upon issuance of the Company's Convertible Notes to long-term debt. Therefore, noncash interest expense during the three and six months ended June 30, 2021 decreased as compared to the same respective periods in 2020, primarily due to a $7 million decrease in amortization associated with the discount attributable to the issuance of the Convertible Notes prior to the adoption of ASU 2020-06. See Note 7 of Notes to Consolidated Financial Statements in "Item 1. Financial Statements" for additional information.

The increase in cash interest expense during the three and six months ended June 30, 2021, as compared to the same respective periods in 2020, is primarily due to (i) the changes in long-term debt as a result of the Parsley Acquisition and DoublePoint Acquisition (see "Liquidity and Capital Resources" below for further information) and (ii) the issuance in May 2020 and August 2020, respectively, of $1.3 billion of the Convertible Notes and $1.1 billion of 1.90% senior notes due 2030, partially offset by (i) the partial repayment of $360 million of the Company's 3.45% senior notes due 2021, $356 million of its 3.95% senior notes due 2022 and $9 million of its 7.20% senior notes due 2028 as a result of the Company's tender offer for these notes in May 2020 and (ii) the repayment of its 3.45% senior notes that matured in January 2021.

The weighted average cash interest rate on the Company's indebtedness for the six months ended June 30, 2021 was 1.9 percent, as compared to 2.4 percent for the same period in 2020. See Note 7 of Notes to Consolidated Financial Statements in "Item 1. Financial Statements" for additional information.

Other expense.


	Three Months Ended June 30,						Six Months Ended June 30,
	2021		2020		Change		2021		2020		Change

	(in millions)
Other expense	$	47	$	90	$	(43)	$	351	$	175	$	176

The decrease in other expense during the three months and increase in the six months ended June 30, 2021, as compared to the same respective periods in 2020, was primarily due to the following:

•$36 million and $233 million of transaction-related costs for the three and six months ended June 30, 2021, respectively, associated with the Parsley Acquisition and DoublePoint Acquisition;

•$80 million of losses for the six months ended June 30, 2021 related to the Company's fulfillment of certain firm gas purchase commitments during Winter Storm Uri in February 2021; and

•$7 million and $17 million of costs primarily related to unoccupied facilities acquired through the Parsley Acquisition for the three and six months ended June 30, 2021, respectively; as compared to

•a $69 million charge for estimated deficiency payments related to the Company's South Texas Divestiture for the six months ended June 30, 2020;

•$44 million and $53 million of idle frac fleet fees, stacked drilling rig charges and drilling rig early termination charges for the three and six months ended June 30, 2020, respectively; and

•$27 million of early extinguishment of debt charges for the three and six months ended June 30, 2020 associated with the Company's refinancing activities during the second quarter of 2020.

See Note 14 of Notes to Consolidated Financial Statements in "Item 1. Financial Statements" for additional information.

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Income tax benefit (provision).


	Three Months Ended June 30,									Six Months Ended June 30,
	2021			2020			Change			2021			2020			Change

	(in millions)
Income tax benefit (provision)	$	(120)		$	109		$	(229)		$	(109)		$	31		$	(140)

Effective tax rate	24		%	20		%	4		%	26		%	17		%	9		%

The change in income tax benefit (provision) during the three and six months ended June 30, 2021, as compared to the same periods in 2020, was primarily due to a $1.1 billion and $608 million increase, respectively, in income before income taxes. The Company evaluates and updates its annual effective income tax rate on an interim basis based on current and forecasted earnings and tax laws. The mix and timing of the Company's actual earnings compared to annual projections can cause interim effective tax rate fluctuations. The Company's interim effective tax rate for the three and six months ended June 30, 2021 differed from the U.S. statutory rate of 21 percent primarily due to forecasted state income taxes. See Note 15 of Notes to Consolidated Financial Statements included in "Item 1. Financial Statements" for additional information.

Liquidity and Capital Resources

Liquidity. The Company's primary sources of short-term liquidity are (i) cash and cash equivalents, (ii) net cash provided by operating activities, (iii) sales of investments, (iv) unused borrowing capacity under its Credit Facility, (v) issuances of debt or equity securities and (vi) other sources, such as sales of nonstrategic assets. In January 2021, Pioneer entered into the First Amendment to Credit Agreement, with the primary changes being to increase the aggregate loan commitments from $1.5 billion to $2.0 billion, extend the maturity of the Credit Facility to January 12, 2026 and to nominally adjust the drawn and undrawn pricing.

The Company's short-term and long-term liquidity requirements consist primarily of (i) capital expenditures, (ii) acquisitions of oil and gas properties, (iii) payments of contractual obligations, including debt maturities, (iv) dividends and share repurchases and (v) working capital obligations. Funding for these requirements may be provided by any combination of the Company's sources of liquidity. Although the Company expects that its sources of funding will be adequate to fund its 2021 liquidity requirements, no assurance can be given that such funding sources will be adequate to meet the Company's future needs.

During the six months ended June 30, 2021, the Company enhanced its liquidity position by refinancing a portion of the debt acquired in the Parsley Acquisition and the DoublePoint Acquisition, issuing new debt and increasing borrowing capacity under the Company's Credit Facility, with the combined objective of increasing liquidity, extending the Company's debt maturities and lowering the Company's future cash interest expense on long-term debt.

2021 revised capital budget. With the completion of the Parsley Acquisition and the DoublePoint Acquisition, the Company's capital budget for 2021 was revised and is expected to be in the range of $3.1 billion to $3.4 billion, consisting of $2.95 billion to $3.25 billion for drilling and completion related activities, including additional tank batteries, saltwater disposal facilities, water infrastructure additions and vehicles, and $150 million of estimated Parsley and DoublePoint integration costs. The Company's capital expenditures for the six months ended June 30, 2021 were $1.5 billion. The 2021 capital budget and actual capital expenditures for the six months ended June 30, 2021 excludes acquisitions, asset retirement obligations, capitalized interest, geological and geophysical general and administrative expense and corporate facilities.

Capital resources. As of June 30, 2021, the Company had no outstanding borrowings under its Credit Facility, leaving $2.0 billion of unused borrowing capacity. The Company was in compliance with all of its debt covenants as of June 30, 2021. The Company also had unrestricted cash on hand of $93 million as of June 30, 2021.

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Cash flows from operating, investing and financing activities are summarized below.


	Six Months Ended June 30,
	2021		2020		Change

	(in millions)
Net cash provided by operating activities	$	1,843	$	1,154	$	689
Net cash used in investing activities	$	(2,042)	$	(1,106)	$	936
Net cash used in financing activities	$	(1,160)	$	(504)	$	656

Operating activities. The increase in net cash flow provided by operating activities for the six months ended June 30, 2021, as compared to the same period in 2020, was primarily due to an increase in oil and gas revenues as a result of higher commodity prices and sales volumes partially offset by (i) additional cash used in derivative activities, (ii) an increase in production costs due to an increase in production taxes attributable to higher commodity prices and costs attributable to the production added from the from the Parsley Acquisition and the DoublePoint Acquisition, (iii) one-time cash Parsley and DoublePoint transaction-related costs and (iv) cash paid to fulfill certain gas commitments during Winter Storm Uri.

Investing activities. The increase in net cash used in investing activities for the six months ended June 30, 2021, as compared to the same period in 2020, was primarily a result of $943 million of net cash used in the DoublePoint Acquisition and an increase in additions to oil and gas properties of $159 million, partially offset by (i) $117 million of net cash acquired in the Parsley Acquisition, (ii) an increase in proceeds from disposition of assets of $25 million primarily related to the sale of the Company's well services business and (iii) a decrease in additions to other assets and other property and equipment of $24 million.

Financing activities. The Company's significant financing activities are as follows:

•2021: The Company (i) received proceeds from the May 2021 Senior Notes Offering, net of $4 million of issuance costs and discounts, of $746 million, (ii) received proceeds from the January 2021 Senior Notes Offering, net of $24 million of issuance costs and discounts, of $2.5 billion, (iii) borrowed and repaid $650 million on the Company's Credit Facility, (iv) repaid the Parsley and DoublePoint credit facilities, which had outstanding balances of $397 million and $240 million, respectively, (v) repaid $140 million associated with the maturity of its 3.45% senior notes due in January 2021, (vi) used proceeds from the May 2021 Senior Notes Offering to pay $731 million to redeem DoublePoint's 7.75% senior notes due 2023, (vii) used proceeds from the January 2021 Senior Notes Offering to pay $1.6 billion to redeem Parsley's 5.250% senior notes due 2025, Parsley's 5.375% senior notes due 2025 and Jagged Peak's 5.875% senior notes due 2026, (viii) paid $852 million to purchase a portion of Parsley's 5.625% senior notes due 2027 and Parsley's 4.125% senior notes due 2028 pursuant to a cash tender offer, (ix) paid $147 million of other liabilities and (x) paid dividends of $213 million.

•2020: The Company (i) received $1.3 billion from the issuance of the Convertible Notes, net of issuance fees, (ii) paid $113 million to enter into the Capped Call transactions associated with the Convertible Notes issuance, (iii) repaid an aggregate of $725 million associated with the early repayment of a portion of the 3.45% senior notes, 3.95% senior notes and 7.20% senior notes, (iv) repaid $450 million associated with the maturity of its 7.50% senior notes in January 2020, (v) purchased $172 million of treasury stock, (vi) paid dividends of $164 million and (vii) paid $154 million of other liabilities.

Dividends/distributions. During the six months ended June 30, 2021, the Company paid dividends of $213 million, or $1.11 per share. In May 2021, the board of directors declared a quarterly cash dividend of $0.56 per share on the Company's outstanding common stock, payable on July 14, 2021, to stockholders of record on June 30, 2021.

In addition to its base dividend program, the Company has initiated a variable dividend strategy whereby the Company may pay a quarterly variable dividend of up to 75 percent of the prior quarter free cash flow remaining after the payment of the base dividend. On August 2, 2021, the Company declared an inaugural variable dividend of $1.51 per share for shareholders of record on September 3, 2021, with a payment date of September 17, 2021.

Free cash flow is a non-GAAP financial measure. As used by the Company, free cash flow is defined as net cash provided by operating activities, adjusted for changes in operating assets and liabilities and cash transaction costs associated with acquisitions, less capital expenditures. The Company believes this non-GAAP measure is a financial indicator of the Company's ability to internally fund acquisitions, debt maturities, dividends and share repurchases after capital expenditures.

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Capital expenditures exclude acquisitions, asset retirement obligations, capitalized interest, geological and geophysical general and administrative expenses, information technology capital and additions to corporate facilities.

Future base and variable dividends are at the discretion of the Company's board of directors, and, if declared, the board of directors may change the dividend amount based on the Company's outlook for commodity prices, liquidity, debt levels, capital resources, free cash flow and other factors. The Company can provide no assurance that dividends will be authorized or declared in the future or as to the amount of any future dividends. Any future variable dividends, if declared and paid, will by their nature fluctuate based on the Company's free cash flow, which will depend on a number of factors beyond the Company's control, including commodities prices.

Off-balance sheet arrangements. From time to time, the Company enters into arrangements and transactions that can give rise to material off-balance sheet obligations. As of June 30, 2021, the material off-balance sheet arrangements and transactions that the Company had entered into included (i) firm purchase, transportation, storage and fractionation commitments, (ii) open purchase commitments and (iii) contractual obligations for which the ultimate settlement amounts are not fixed and determinable. The contractual obligations for which the ultimate settlement amounts are not fixed and determinable include (a) derivative contracts that are sensitive to future changes in commodity prices or interest rates, (b) gathering, processing (primarily treating and fractionation) and transportation commitments on uncertain volumes of future throughput and (c) indemnification obligations following certain divestitures.

In connection with its divestiture transactions, the Company may retain certain liabilities and provide the purchaser certain indemnifications, subject to defined limitations, which may apply to identified pre-closing matters, including matters of litigation, environmental contingencies, royalty and income taxes. Also associated with its divestiture transactions, the Company has issued and received guarantees to facilitate the transfer of contractual obligations, such as firm transportation agreements or gathering and processing arrangements. The Company does not recognize a liability if the fair value of the obligation is immaterial and the likelihood of making payments under these guarantees is remote.

Other than the off-balance sheet arrangements described above, the Company has no transactions, arrangements or other relationships with unconsolidated entities or other persons that are reasonably likely to materially affect the Company's liquidity or availability of or requirements for capital resources. The Company expects to enter into similar contractual arrangements in the future, including incremental derivative contracts and additional firm purchase, transportation, storage and fractionation arrangements, in order to support the Company's business plans. See "Contractual obligations" below and Note 10 of Notes to Consolidated Financial Statements included in "Item 1. Financial Statements" for additional information.

The Convertible Notes are convertible into shares of the Company's common stock at a conversion rate of 9.111 shares of the Company's common stock per $1,000 principal amount of the Convertible Notes (subject to adjustment pursuant to the terms of the notes indenture, the "Conversion Rate"), which represents a conversion price of $109.76 per share (subject to adjustment pursuant to the terms of the notes indenture, the "Conversion Price"). As a result of the quarterly base dividends declared through March 31, 2021, the Conversion Rate increased from the initial rate of 9.1098 shares of the Company's common stock per $1,000 principal amount of the Convertible Notes and the Conversion Price decreased from $109.77. Future changes to the Company's base dividend program or the declaration of a variable dividend, as previously described, will cause an adjustment to the Conversion Rate and the Conversion Price pursuant to the terms of the notes indenture. Upon conversion, the Convertible Notes may be settled in cash, shares of the Company's common stock or a combination thereof, at the Company's election.

Holders of the Convertible Notes may convert their notes at their option prior to February 15, 2025 under the following circumstances:

•upon notice of redemption by the Company; or

•upon the occurrence of specified corporate events, including certain consolidations or mergers.

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During the last 30 consecutive trading days of the second quarter of 2021, the last reported sales prices of the Company's common stock exceeded 130 percent of the Conversion Price for at least 20 trading days, causing the Convertible Notes to become convertible at the option of the holders during the three month period ending September 30, 2021. If converted by the holder, the Company intends to settle the Convertible Notes in cash, although the Company reserves its right under the notes indenture to elect to settle the Convertible Notes in shares of the Company's common stock or a combination of cash and common stock.

Contractual obligations. The Company's contractual obligations include long-term debt, leases (primarily related to contracted drilling rigs, equipment and office facilities), capital funding obligations, derivative obligations, firm transportation, storage and fractionation commitments, minimum annual gathering, processing and transportation commitments and other liabilities (including postretirement benefit obligations). Other joint owners in the properties operated by the Company could incur portions of the costs represented by these commitments.

The Company has short-term and long-term firm purchase, gathering, processing, transportation, fractionation and storage commitments representing take-or-pay agreements, which include contractual commitments (i) to purchase sand, water and diesel for use in the Company's drilling and completion operations, (ii) with midstream service companies and pipeline carriers for future gathering, processing, transportation, fractionation and storage and (iii) with oilfield services companies that provide drilling and pressure pumping services. The Company does not expect to be able to fulfill all of its short-term and long-term firm transportation volume obligations from projected production of available reserves; consequently, the Company plans to purchase third party volumes to satisfy its firm transportation commitments if it is economic to do so; otherwise, it will pay demand fees for any commitment shortfalls.

The Company's commodity and marketing derivative contracts are periodically measured and recorded at fair value and continue to be subject to market and credit risk. As of June 30, 2021, these contracts represented net liabilities of $1.3 billion. The ultimate liquidation value of the Company's commodity derivatives will be dependent upon actual future commodity prices, which may differ materially from the inputs used to determine the derivatives' fair values as of June 30, 2021. See Note 5 of Notes to Consolidated Financial Statements included in "Item 1. Financial Statements" and "Item 3. Quantitative and Qualitative Disclosures About Market Risk" for additional information.

New Accounting Pronouncements

The effects of new accounting pronouncements are discussed in Note 2 of Notes to Consolidated Financial Statements included in "Item 1. Financial Statements."


ITEM 3.			QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

In the normal course of business, the Company's financial position is routinely subject to a variety of risks, including market risks associated with changes in commodity prices, interest rate movements on outstanding debt and credit risks. These risks are mitigated through the Company's risk management program, which includes the use of derivative financial instruments and selling purchased oil and gas outside of the Permian Basin. The following quantitative and qualitative information is provided about financial instruments to which the Company was a party as of June 30, 2021, and from which the Company may incur future gains or losses from changes in commodity prices or interest rates. The Company does not enter into any financial instruments, including derivatives, for speculative or trading purposes.

Interest rate risk. As of June 30, 2021, the Company had no variable rate debt outstanding under the Credit Facility and, consequently, no related exposure to interest rate risk. As of June 30, 2021, the Company had $6.9 billion of fixed rate long-term debt outstanding with a weighted average cash interest rate of 1.9 percent. Although changes in interest rates may affect the fair value of the Company's fixed rate long-term debt, any changes would not impact earnings or expose the Company to the risk of cash flow losses. The Company did not have any interest rate derivative instruments outstanding as of June 30, 2021; however, it may enter into such instruments in the future to mitigate interest rate risk. See Note 4 and Note 7 of Notes to Consolidated Financial Statements included in "Item 1. Financial Statements" for additional information.

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Commodity price risk. The Company's primary market risk exposure is related to the price it receives from the sale of its oil, NGLs and gas production. Realized pricing is volatile and is determined by market prices that fluctuate with changes in supply and demand for these products throughout the world. The price the Company receives for its production depends on many factors outside of the control of the Company, including differences in commodity pricing at the point of sale versus market index prices. Reducing the Company's exposure to price volatility helps secure funds to be used in its capital program and to fund general working capital needs, debt obligations, dividends and share repurchases, among other uses. The Company mitigates its commodity price risk through the use of derivative financial instruments and sales of purchased oil and gas.

Derivative financial instruments. The Company's decision on the quantity and price at which it executes derivative contracts is based in part on its view of current and future market conditions. The Company may choose not to enter into derivative positions for expected production if the commodity price forecast for certain time periods is deemed to be unfavorable. Additionally, the Company may choose to liquidate existing derivative positions prior to the expiration of their contractual maturity in order to monetize gain positions or minimize loss positions if it is anticipated that the commodity price forecast is expected to improve. Proceeds, if any, can be used for the purpose of funding the Company's capital program, general working capital needs, debt obligations, dividends and share repurchases, among other uses. While derivative positions limit the downside risk of adverse price movements, they also limit future revenues from upward price movements. The Company manages commodity price risk with the following types of commodity derivative contracts:

•Swaps. The Company receives a fixed price and pays a floating market price to the counterparty on a notional amount of sales volumes, thereby fixing the price for the commodity sold.

•Collars. Collar contracts provide minimum ("floor" or "long put") and maximum ("ceiling") prices on a notional amount of sales volumes, thereby allowing some price participation if the relevant index price closes above the floor price but below the ceiling price.

•Collar contracts with short put options. Collar contracts with short put options differ from other collar contracts by virtue of the short put option price, below which the Company's realized price will exceed the variable market prices by the long put-to-short put price differential.

•Basis swaps. Basis swap contracts fix the basis differentials between the index price at which the Company sells its production and the index price used in swap or collar contracts.

•Rollfactor swaps. Rollfactor swaps are utilized to match the derivative contracts to the physical oil sales. Physical oil sales typically use trade month averages whereas derivative contracts utilize calendar month averages. The rollfactor swaps convert the calendar month into a trade month.

•Options. Selling individual call options can enhance the market price by the premium received or, alternatively, the premium received can be utilized to improve swap or collar contract prices. Purchased put options establish a minimum floor price (less any premiums paid) and allow participation in higher prices when prices close above the floor price.

The Company has entered into commodity derivative contracts for a portion of its forecasted 2021 and 2022 production; consequently, if commodity prices decline, the Company could realize lower prices for volumes not protected by the Company's derivative activities and could see a reduction in derivative contract prices on additional volumes in the future. As a result, the Company's internal cash flows will be negatively impacted by a reduction in commodity prices.

The average forward prices based on June 30, 2021 market quotes were as follows:


	2021				Year Ending December 31, 2022
	Third Quarter		Fourth Quarter
Average forward Brent oil price	$	73.82	$	71.79	$	68.54
Average forward WTI Midland oil price	$	71.76	$	69.43	$	65.48
Average forward MEH oil price	$	72.14	$	69.91	$	66.15
Average forward NYMEX gas price	$	3.64	$	3.67	$	3.17
Average forward DUTCH TTF gas price	$	12.02	$	12.12	$	8.94
Average forward WAHA gas price	$	3.57	$	3.56	$	2.83
WTI Midland/Brent oil basis differentials:


Average forward basis differential price (a)	$	(2.06)	$	(2.36)	$	(3.06)

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The average forward prices based on July 30, 2021 market quotes are as follows:


	2021				Year Ending December 31, 2022
	Third Quarter		Fourth Quarter
Average forward Brent oil price	$	75.44	$	73.11	$	69.63
Average forward WTI Midland oil price	$	73.11	$	70.86	$	66.63
Average forward MEH oil price	$	73.54	$	71.34	$	67.28
Average forward NYMEX gas price	$	3.91	$	4.00	$	3.46
Average forward DUTCH TTF gas price	$	14.18	$	14.14	$	9.61
Average forward WAHA gas price	$	3.68	$	3.79	$	3.14
WTI Midland/Brent oil basis differentials:


Average forward basis differential price (a)	$	(2.34)	$	(2.25)	$	(3.00)

___________________

(a)Based on market quotes for basis differentials between Midland oil index prices and the Brent oil index price.

See Note 4 and Note 5 of Notes to Consolidated Financial Statements included in "Item 1. Financial Statements" for a description of the Company's open derivative positions and additional information.

Sales of purchased commodities. The Company enters into purchase transactions with third parties and separate sale transactions with third parties to diversify a portion of the Company's oil and gas sales to (i) Gulf Coast refineries, (ii) Gulf Coast and West Coast gas markets and (iii) international oil markets and to satisfy unused gas pipeline capacity commitments. The Company also enters into pipeline capacity commitments to secure diesel supply from the Gulf Coast to the Company's operations in the Permian Basin. The Company enters into separate sales transactions with third parties related to diesel volumes that exceed the Company's operational needs.

Marketing derivatives. The Company's marketing derivatives reflect two long-term marketing contracts that were entered in October 2019 whereby the Company agreed to purchase and simultaneously sell 50 thousand barrels of oil per day at an oil terminal in Midland, Texas for a six-year term that began on January 1, 2021 and ends on December 31, 2026. The price the Company pays to purchase the oil volumes under the purchase contract is based on a Midland WTI price and the price the Company receives for the oil volumes sold is a WASP that a non-affiliated counterparty receives for selling oil through their Gulf Coast storage and export facility at prices that are highly correlated with Brent oil prices during the same month of the purchase. Based on the form of the marketing contracts, the Company determined that the marketing contracts should be accounted for as derivative instruments. Similar to sales of purchased commodities, these marketing derivatives allow the Company to diversify a portion of its oil sales from its area of production to Gulf Coast and international markets.

The average forward prices based on June 30, 2021 market quotes are as follows:


	Year Ending
	December 31, 2021		December 31, 2022		December 31, 2023		December 31, 2024		December 31, 2025		December 31, 2026
Average forward Brent oil price	$	72.81	$	68.54	$	64.59	$	61.77	$	59.96	$	59.11
Average forward WTI Midland oil price	70.60		65.48		60.86		57.56		55.48		54.42
Average forward basis differential price (a)	$	2.21	$	3.06	$	3.73	$	4.21	$	4.48	$	4.69

The average forward prices based on July 30, 2021 market quotes are as follows:


	Year Ending
	December 31, 2021		December 31, 2022		December 31, 2023		December 31, 2024		December 31, 2025		December 31, 2026
Average forward Brent oil price	$	74.28	$	69.63	$	65.48	$	62.33	$	60.14	$	58.94
Average forward WTI Midland oil price	71.98		66.63		61.42		57.68		55.18		53.72
Average forward basis differential price (a)	$	2.30	$	3.00	$	4.06	$	4.65	$	4.96	$	5.22

___________________

(a)Based on market quotes for basis differentials between Midland oil index prices and the Brent oil index price.

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PIONEER NATURAL RESOURCES COMPANY

Credit risk. The Company's primary concentration of credit risks are associated with the collection of receivables resulting from the sale of oil and gas production and purchased oil and gas, and the risk of a counterparty's failure to meet its obligations under derivative contracts with the Company.

The Company's commodities are sold to various purchasers who must be prequalified under the Company's credit risk and procedures. The Company monitors exposure to counterparties primarily by reviewing credit ratings, financial criteria and payment history. Where appropriate, the Company obtains assurances of payment, such as a guarantee by the parent company of the counterparty, a letter of credit or other credit support. Historically, the Company's credit losses on commodities receivables have not been material.

The Company has entered into International Swap Dealers Association Master Agreements ("ISDA Agreements") with each of its derivative counterparties. The terms of the ISDA Agreements provide the Company and the counterparties with right of set off upon the occurrence of defined acts of default by either the Company or a counterparty to a derivative contract, whereby the party not in default may set off all derivative liabilities owed to the defaulting party against all derivative asset receivables from the defaulting party. See Note 5 of Notes to Consolidated Financial Statements included in "Item 1. Financial Statements" for additional information.


ITEM 4.			CONTROLS AND PROCEDURES

Evaluation of disclosure controls and procedures. The Company's management, with the participation of its principal executive officer and principal financial officer, have evaluated, as required by Rule 13a-15(b) under the Securities Exchange Act of 1934 (the "Exchange Act"), the effectiveness of the Company's disclosure controls and procedures (as defined in Exchange Act Rule 13a-15(e)) as of the end of the period covered by this Report. Based on that evaluation, the principal executive officer and principal financial officer concluded that the Company's disclosure controls and procedures were effective, as of the end of the period covered by this Report, in ensuring that information required to be disclosed by the Company in the reports that it files or submits under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the SEC's rules and forms, including that such information is accumulated and communicated to the Company's management, including the principal executive officer and principal financial officer, to allow timely decisions regarding required disclosure.

Changes in internal control over financial reporting. There have been no changes in the Company's internal control over financial reporting (as defined in Rule 13a-15(f) under the Exchange Act) that occurred during the three months ended June 30, 2021 that have materially affected or are reasonably likely to materially affect the Company's internal control over financial reporting.

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PIONEER NATURAL RESOURCES COMPANY

PART II. OTHER INFORMATION


ITEM 1.			LEGAL PROCEEDINGS

The Company is party to various proceedings and claims incidental to its business. While many of these matters involve inherent uncertainty, the Company believes that the amount of the liability, if any, ultimately incurred with respect to these proceedings and claims will not have a material adverse effect on the Company's consolidated financial position as a whole or on its liquidity, capital resources or future annual results of operations.


ITEM 1A.			RISK FACTORS

In addition to the information set forth in this Report, the risks that are discussed in the Company's Annual Report on Form 10-K for the year ended December 31, 2020, under the headings "Part I, Item 1. Business – Competition," "Part I. Item 1. Business - Regulation," "Part I, Item 1A. Risk Factors," "Part II, Item 7A. Quantitative and Qualitative Disclosures About Market Risk" as updated by the discussion in Part II of the Company's Quarterly Report on Form 10-Q for the quarter ended March, 31, 2021, should be carefully considered, as such risks could materially affect the Company's business, financial condition or future results. There has been no material change in the Company's risk factors that were described in the Company's 2020 Annual Report on Form 10-K except as updated by the referenced Form 10-Q.

These risks are not the only risks facing the Company. Additional risks and uncertainties not currently known to the Company or that it currently deems to be immaterial also may have a material adverse effect on the Company's business, financial condition or future results.


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

Purchases of Equity Securities by the Issuer and Affiliated Purchasers

Purchases of the Company's common stock are as follows:


	Three Months Ended June 30, 2021
Period	Total Number of Shares Purchased (a)	Average Price Paid per Share		Total Number of Shares Purchased As Part of Publicly Announced Plans or Programs	Approximate Dollar Amount of Shares that May Yet Be Purchased under Plans or Programs (b)
April 2021	2,122	$	151.38	—	$	1,090,693,887
May 2021	3	$	157.05	—	$	1,090,693,887
June 2021	—	$	—	—	$	1,090,693,887
	2,125			—

____________________

(a)Includes shares purchased from employees in order for employees to satisfy income tax withholding payments related to share-based awards that vested during the period.

(b)In December 2018, the Company's board of directors authorized a $2 billion common stock repurchase program. The stock repurchase program has no time limit and may be modified, suspended or terminated at any time by the board of directors.

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PIONEER NATURAL RESOURCES COMPANY


ITEM 6.			EXHIBITS

Exhibit
Number

Description

4.1

Fifth Supplemental Indenture, dated May 18, 2021, by and between the Company and Wells Fargo Bank, National Association (incorporated by reference to Exhibit 4.1 to the Company's Current Report on Form 8-K, File No. 1-13245, filed with the SEC on May 18, 2021).

10.1 (a)

Sixth Amendment to Pioneer Natural Resources USA, Inc. 401 (k) and Matching Plan

10.2

Amended and Restated Pioneer Natural Resources Company Employee Stock Purchase Plan dated effective September 1, 2021 (incorporated by reference to Exhibit 10.1 to the Company's Current Report on Form 8-K, File No. 1-13245, filed with the SEC on June 1, 2021)

10.3 (a)

Indemnification Agreement, dated as of June 24, 2021, between the Company and Lori G. Billingsley.

31.1 (a)

Chief Executive Officer certification under Section 302 of Sarbanes-Oxley Act of 2002.

31.2 (a)

Chief Financial Officer certification under Section 302 of Sarbanes-Oxley Act of 2002.

32.1 (b)

Chief Executive Officer certification under Section 906 of Sarbanes-Oxley Act of 2002.

32.2 (b)

Chief Financial Officer certification under Section 906 of Sarbanes-Oxley Act of 2002.

101.INS (a)

Inline XBRL Instance Document - the instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document.

101.SCH (a)

Inline XBRL Taxonomy Extension Schema Document.

101.CAL (a)

Inline XBRL Taxonomy Extension Calculation Linkbase Document.

101.DEF (a)

Inline XBRL Taxonomy Extension Definition Linkbase Document.

101.LAB (a)

Inline XBRL Taxonomy Extension Label Linkbase Document.

101.PRE (a)

Inline XBRL Taxonomy Extension Presentation Linkbase Document.

104

Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101).

____________________

(a)Filed herewith.

(b)Furnished herewith.

* Schedules have been omitted pursuant to Item 601(b)(2) of Regulation S-K. The Company agrees to furnish to the SEC a copy of any omitted schedule upon request.

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PIONEER NATURAL RESOURCES COMPANY

SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the Registrant has duly caused this Report to be signed on its behalf by the undersigned hereto duly authorized.

PIONEER NATURAL RESOURCES COMPANY

August 5, 2021

By:

/s/ Neal H. Shah

Neal H. Shah

Senior Vice President and Chief Financial Officer

August 5, 2021

By:

/s/ Margaret M. Montemayor

Margaret M. Montemayor

Vice President and Chief Accounting Officer