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false 0001389170 0001389170 2020-08-06 2020-08-06

  

 

UNITED STATES SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 8-K

CURRENT REPORT PURSUANT TO SECTION 13 OR 15(d)

OF THE SECURITIES EXCHANGE ACT OF 1934

Date of Report (Date of earliest event reported):

August 6, 2020

TARGA RESOURCES CORP.

(Exact name of registrant as specified in its charter)

 

 

 

 

 

 

 

 

 

 

Delaware

(State or other jurisdiction

of incorporation or organization)

 

001-34991

(Commission

File Number)

 

20-3701075

(IRS Employer

Identification No.)

 

811 Louisiana, Suite 2100

Houston, TX 77002

(Address of principal executive office and Zip Code)

 

(713) 584-1000

(Registrants’ telephone number, including area code)

 

Check the appropriate box below if the Form 8-K filing is intended to simultaneously satisfy the filing obligation of the registrant under any of the following provisions:

 

 

Written communications pursuant to Rule 425 under the Securities Act (17 CFR 230.425)

 

 

 

 

Soliciting material pursuant to Rule 14a-12 under the Exchange Act (17 CFR 240.14a-12)

 

 

 

 

Pre-commencement communications pursuant to Rule 14d-2(b) under the Exchange Act (17 CFR 240.14d-2(b))

 

 

 

 

Pre-commencement communications pursuant to Rule 13e-4(c) under the Exchange Act (17 CFR 240.13e-4(c))

 

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

 

Title of each class

Trading Symbol(s)

Name of exchange on which registered

Common Stock

TRGP

New York Stock Exchange

 

Indicate by check mark whether the registrant is an emerging growth company as defined in Rule 405 of the Securities Act of 1933 (§230.405 of this chapter) or Rule 12b-2 of the Securities Exchange Act of 1934 (§240.12b-2 of this chapter). 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. 

 

 


   

Item 2.02

 

Results of Operations and Financial Condition.

 

On August 6, 2020, Targa Resources Corp. (the “Company”) issued a press release regarding its financial results for the three months ended June 30, 2020. A conference call to discuss these results is scheduled for 11:00 a.m. Eastern time (10:00 a.m. Central time) on Thursday, August 6, 2020. The conference call will be webcast live and a replay of the webcast will be available through the Investors section of the Company’s web site (http://www.targaresources.com). A copy of the earnings press release is furnished as Exhibit 99.1 to this report, which is hereby incorporated by reference into this Item 2.02.

 

The press release and accompanying schedules and/or the conference call discussions include the non-generally accepted accounting principles (“non-GAAP”) financial measures of distributable cash flow, gross margin, operating margin and adjusted EBITDA. The press release provides reconciliations of these non-GAAP financial measures to their most directly comparable financial measure calculated and presented in accordance with generally accepted accounting principles in the United States of America (“GAAP”). Our non-GAAP financial measures should not be considered as alternatives to GAAP measures such as net cash provided by operating activities, net income (loss) or any other GAAP measure of liquidity or financial performance.

 

The information furnished pursuant to this Item 2.02, including Exhibit 99.1, shall not be deemed to be “filed” for the purposes of Section 18 of the Securities Exchange Act of 1934, as amended, and will not be incorporated by reference into any filing under the Securities Act of 1933, as amended, unless specifically identified therein as being incorporated therein by reference.

 

 

Item 9.01

 

Financial Statements and Exhibits.

 

(d) Exhibits

 

Exhibit

 

 

Number

 

Description

Exhibit 99.1

 

Targa Resources Corp. Press Release dated August 6, 2020.

 

 

 

Exhibit 104

 

Cover Page Interactive Data File (embedded within the Inline XBRL document).

 

 

 

 

 

SIGNATURES

 

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

 

Targa Resources Corp.

 

 

Date: August 6, 2020

By:

/s/ Jennifer R. Kneale

 

 

Jennifer R. Kneale

 

 

Chief Financial Officer

(Principal Financial Officer)

 

trgp-ex991_33.htm

 

Exhibit 99.1

811 Louisiana, Suite 2100

Houston, TX 77002

713.584.1000

 

Targa Resources Corp. Reports

Second Quarter 2020 Financial Results

 

HOUSTON – August 6, 2020 - Targa Resources Corp. (NYSE: TRGP) (“TRC”, the “Company” or “Targa”) today reported second quarter 2020 results.

 

Second Quarter 2020 Financial Results

 

Second quarter 2020 net income (loss) attributable to Targa Resources Corp. was $81.0 million compared to a net loss of $(10.2) million for the second quarter of 2019.

 

The Company reported quarterly earnings before interest, income taxes, depreciation and amortization, and other non-cash items (“Adjusted EBITDA”) of $351.2 million for the second quarter of 2020 compared to $306.5 million for the second quarter of 2019 (see the section of this release entitled “Targa Resources Corp. ― Non-GAAP Financial Measures” for a discussion of Adjusted EBITDA, distributable cash flow, gross margin and operating margin, and reconciliations of such measures to their most directly comparable financial measures calculated and presented in accordance with U.S. generally accepted accounting principles (“GAAP”)).

 

On July 16, 2020, TRC declared a quarterly dividend of $0.10 per share of its common stock for the three months ended June 30, 2020, or $0.40 per share on an annualized basis. Total cash dividends of approximately $23.3 million will be paid on August 17, 2020 on all outstanding shares of common stock to holders of record as of the close of business on July 31, 2020. Also, on July 16, 2020, TRC declared a quarterly cash dividend of $23.75 per share of its Series A Preferred Stock. Total cash dividends of approximately $22.9 million will be paid on August 14, 2020 on all outstanding shares of Series A Preferred Stock to holders of record as of the close of business on July 31, 2020.

 

The Company reported distributable cash flow for the second quarter of 2020 of $273.7 million compared to total common dividends to be paid of $23.3 million and total Series A Preferred Stock dividends to be paid of $22.9 million.

 

Second Quarter 2020 - Sequential Quarter over Quarter Commentary

 

Targa reported second quarter 2020 Adjusted EBITDA of $351.2 million. The sequential decrease in Adjusted EBITDA was attributable to the low commodity price environment, and temporary production curtailments and reduced producer activity, which resulted in lower volumes across Targa’s Gathering and Processing (“G&P”) and Logistics and Transportation (“L&T”) systems during the second quarter, partially offset by cost reduction measures that resulted in lower aggregate operating and general and administrative expenses despite new assets being placed in-service during the quarter. In the G&P segment, lower sequential gross margin was predominantly attributable to lower volumes in the Badlands and Central region attributable to temporary production shut-ins and reduced producer activity, and lower average commodity price realizations. Targa’s second quarter natural gas inlet volumes in the Permian were relatively flat when compared to the first quarter, despite the impacts of temporary production shut-ins and reduced activity levels during the quarter. In the L&T segment, lower sequential gross margin was primarily due to lower marketing margin, and modestly lower sequential fractionation, pipeline transportation and liquefied petroleum gas (“LPG”) export volumes during the second quarter. Seasonality in Targa’s wholesale marketing businesses, combined with less optimization margin realized in its marketing businesses during the second quarter, accounted for about half of the sequential decline in segment gross margin when compared to the first quarter. Lower fractionation and pipeline transportation volumes were also due to temporary production shut-ins and reduced producer activity. Lower LPG export volumes were attributable to scheduled downtime to tie-in the phased expansion at Targa’s LPG export facility at Galena Park, which began operations in August.

 

Updated 2020 Outlook

 

While commodity prices remain low and uncertainties associated with the impacts of COVID-19 continue, in certain areas of Targa’s operations like the Permian Basin, production from wells that were previously shut-in during the second quarter has largely resumed. Assuming crude oil prices average $40 per barrel WTI, NGL prices average $0.40 per gallon, and Henry Hub and Waha natural gas prices average $2.00 and $1.50 per million British Thermal unit, respectively and the Company’s current best estimates for a range of volume outcomes through the second half of 2020, Targa is increasing the low end of its previously provided 2020 Adjusted EBITDA outlook and now estimates full year Adjusted EBITDA to be between $1.5 billion to $1.625 billion.

 

 

 

 


 

 

Second Quarter 2020 - Capitalization and Liquidity

 

The Company’s total consolidated debt as of June 30, 2020 was $7,841.5 million including $435.0 million outstanding under TRC’s $670.0 million senior secured revolving credit facility. The consolidated debt included $7,406.5 million of Targa Resources Partners LP’s (“TRP” or the “Partnership”) debt, net of $43.7 million of debt issuance costs, with $440.0 million outstanding under TRP’s $2.2 billion senior secured revolving credit facility, $250.0 million outstanding under TRP’s accounts receivable securitization facility, $6,725.1 million of outstanding TRP senior notes, net of unamortized premiums, and $35.1 million of finance lease liabilities.

 

Total consolidated liquidity of the Company as of June 30, 2020, including $196.2 million of cash, was over $2.1 billion. As of June 30, 2020, TRC had available borrowing capacity under its senior secured revolving credit facility of $235.0 million. TRP had $440.0 million of borrowings and $56.8 million in letters of credit outstanding under its $2.2 billion senior secured revolving credit facility, resulting in available senior secured revolving credit facility capacity of $1,703.2 million.

 

Growth Projects Update

 

Since the beginning of 2020, the Company has completed the vast majority of its major growth capital projects underway either on- or under-budget. Targa commenced operations on its 110 thousand barrel per day (“Mbbl/d”) Train 7 fractionator in Mont Belvieu and its 250 million cubic feet per day (“MMcf/d”) Peregrine Plant in Permian Delaware, and has recently commenced operations on its phased expansion at its LPG export facility at Galena Park and its 250 MMcf/d Gateway Plant in Permian Midland. The Company remains on-track to complete its 110 Mbbl/d Train 8 fractionator in Mont Belvieu during the third quarter of 2020 and its Grand Prix NGL Pipeline (“Grand Prix”) extension into Central Oklahoma during the first quarter of 2021.

 

Conference Call

 

The Company will host a conference call for the investment community at 11:00 a.m. Eastern time (10:00 a.m. Central time) on August 6, 2020 to discuss its second quarter results. The conference call can be accessed via webcast through the Events and Presentations section of Targa’s website at www.targaresources.com, by going directly to https://edge.media-server.com/mmc/p/45feoqa5. A webcast replay will be available at the link above approximately two hours after the conclusion of the event.


 


 

Targa Resources Corp. – Consolidated Financial Results of Operations

 

 

Three Months Ended June 30,

 

 

 

 

 

 

 

 

 

 

Six Months Ended June 30,

 

 

 

 

 

 

 

 

 

 

2020

 

 

2019

 

 

2020 vs. 2019

 

 

2020

 

 

2019

 

 

2020 vs. 2019

 

 

(In millions)

 

Revenues:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Sales of commodities

$

1,280.6

 

 

$

1,684.2

 

 

$

(403.6

)

 

 

(24

%)

 

$

3,060.2

 

 

$

3,660.7

 

 

$

(600.5

)

 

 

(16

%)

Fees from midstream services

 

242.9

 

 

 

311.1

 

 

 

(68.2

)

 

 

(22

%)

 

 

512.2

 

 

 

634.0

 

 

 

(121.8

)

 

 

(19

%)

Total revenues

 

1,523.5

 

 

 

1,995.3

 

 

 

(471.8

)

 

 

(24

%)

 

 

3,572.4

 

 

 

4,294.7

 

 

 

(722.3

)

 

 

(17

%)

Product purchases

 

860.6

 

 

 

1,361.6

 

 

 

(501.0

)

 

 

(37

%)

 

 

2,043.6

 

 

 

3,087.6

 

 

 

(1,044.0

)

 

 

(34

%)

Gross margin (1)

 

662.9

 

 

 

633.7

 

 

 

29.2

 

 

 

5

%

 

 

1,528.8

 

 

 

1,207.1

 

 

 

321.7

 

 

 

27

%

Operating expenses

 

183.4

 

 

 

210.2

 

 

 

(26.8

)

 

 

(13

%)

 

 

383.3

 

 

 

400.5

 

 

 

(17.2

)

 

 

(4

%)

Operating margin (1)

 

479.5

 

 

 

423.5

 

 

 

56.0

 

 

 

13

%

 

 

1,145.5

 

 

 

806.6

 

 

 

338.9

 

 

 

42

%

Depreciation and amortization expense

 

204.5

 

 

 

237.2

 

 

 

(32.7

)

 

 

(14

%)

 

 

443.6

 

 

 

474.6

 

 

 

(31.0

)

 

 

(7

%)

General and administrative expense

 

61.5

 

 

 

72.8

 

 

 

(11.3

)

 

 

(16

%)

 

 

121.9

 

 

 

153.6

 

 

 

(31.7

)

 

 

(21

%)

Impairment of long-lived assets

 

 

 

 

 

 

 

 

 

 

 

 

 

2,442.8

 

 

 

 

 

 

2,442.8

 

 

 

 

Other operating (income) expense

 

0.4

 

 

 

(0.2

)

 

 

0.6

 

 

NM

 

 

 

1.6

 

 

 

3.3

 

 

 

(1.7

)

 

 

(52

%)

Income (loss) from operations

 

213.1

 

 

 

113.7

 

 

 

99.4

 

 

 

87

%

 

 

(1,864.4

)

 

 

175.1

 

 

 

(2,039.5

)

 

NM

 

Interest expense, net

 

(96.7

)

 

 

(72.1

)

 

 

(24.6

)

 

 

(34

%)

 

 

(194.7

)

 

 

(152.7

)

 

 

(42.0

)

 

 

(28

%)

Equity earnings (loss)

 

14.9

 

 

 

3.2

 

 

 

11.7

 

 

NM

 

 

 

35.5

 

 

 

5.9

 

 

 

29.6

 

 

NM

 

Gain (loss) from financing activities

 

21.8

 

 

 

 

 

 

21.8

 

 

 

 

 

 

61.1

 

 

 

(1.4

)

 

 

62.5

 

 

NM

 

Change in contingent considerations

 

 

 

 

0.8

 

 

 

(0.8

)

 

 

(100

%)

 

 

 

 

 

(8.9

)

 

 

8.9

 

 

 

100

%

Other, net

 

0.8

 

 

 

 

 

 

0.8

 

 

 

 

 

 

0.8

 

 

 

 

 

 

0.8

 

 

 

 

Income tax (expense) benefit

 

23.2

 

 

 

3.3

 

 

 

19.9

 

 

NM

 

 

 

318.5

 

 

 

6.2

 

 

 

312.3

 

 

NM

 

Net income (loss)

 

177.1

 

 

 

48.9

 

 

 

128.2

 

 

 

262

%

 

 

(1,643.2

)

 

 

24.2

 

 

 

(1,667.4

)

 

NM

 

Less: Net income (loss) attributable to noncontrolling interests

 

96.1

 

 

 

59.1

 

 

 

37.0

 

 

 

63

%

 

 

13.6

 

 

 

73.3

 

 

 

(59.7

)

 

 

(81

%)

Net income (loss) attributable to Targa Resources Corp.

 

81.0

 

 

 

(10.2

)

 

 

91.2

 

 

NM

 

 

 

(1,656.8

)

 

 

(49.1

)

 

 

(1,607.7

)

 

NM

 

Dividends on Series A Preferred Stock

 

22.9

 

 

 

22.9

 

 

 

 

 

 

 

 

 

45.8

 

 

 

45.8

 

 

 

 

 

 

 

Deemed dividends on Series A Preferred Stock

 

9.2

 

 

 

8.1

 

 

 

1.1

 

 

 

14

%

 

 

18.2

 

 

 

16.0

 

 

 

2.2

 

 

 

14

%

Net income (loss) attributable to common shareholders

$

48.9

 

 

$

(41.2

)

 

$

90.1

 

 

 

219

%

 

$

(1,720.8

)

 

$

(110.9

)

 

$

(1,609.9

)

 

NM

 

Financial data:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Adjusted EBITDA (1)

$

351.2

 

 

$

306.5

 

 

$

44.7

 

 

 

15

%

 

$

779.3

 

 

$

620.6

 

 

$

158.7

 

 

 

26

%

Distributable cash flow (1)

 

273.7

 

 

 

192.0

 

 

 

81.7

 

 

 

43

%

 

 

575.5

 

 

 

388.8

 

 

 

186.7

 

 

 

48

%

Growth capital expenditures (2)

 

142.8

 

 

 

821.4

 

 

 

(678.6

)

 

 

(83

%)

 

 

420.1

 

 

 

1,691.5

 

 

 

(1,271.4

)

 

 

(75

%)

Maintenance capital expenditures (3)

 

26.8

 

 

 

35.5

 

 

 

(8.7

)

 

 

(25

%)

 

 

53.7

 

 

 

71.1

 

 

 

(17.4

)

 

 

(24

%)

 

(1)

Gross margin, operating margin, Adjusted EBITDA, and distributable cash flow are non-GAAP financial measures and are discussed under “Targa Resources Corp. – Non-GAAP Financial Measures.”

(2)

Growth capital expenditures, net of contributions from noncontrolling interest, were $404.2 million and $1,440.5 million for the six months ended June 30, 2020 and 2019. Net contributions to investments in unconsolidated affiliates were $0.3 million and $57.3 million for the six months ended June 30, 2020 and 2019.

(3)

Maintenance capital expenditures, net of contributions from noncontrolling interests, were $51.4 million and $67.2 million for the six months ended June 30, 2020 and 2019.

NM

Due to a low denominator, the noted percentage change is disproportionately high and as a result, considered not meaningful.

 

Three Months Ended June 30, 2020 Compared to Three Months Ended June 30, 2019

 

The decrease in commodity sales reflects lower natural gas liquid (“NGL”), condensate, and petroleum products prices ($476.2 million) and lower crude marketing, petroleum products, and natural gas volumes ($150.3 million), partially offset by higher NGL and condensate volumes ($137.9 million), higher natural gas prices ($59.5 million) and the favorable impact of hedges ($26.1 million).

 

The decrease in fees from midstream services is primarily due to new transportation arrangements for Badlands volumes effective in January 2020, which resulted in a change from net presentation as fees from midstream services to gross presentation as sales of commodities and product purchases, partially offset by increased export volumes.

 

The decrease in product purchases reflects decreased NGL, condensate and petroleum products prices, partially offset by increases in volumes.

 

Higher operating margin and gross margin in 2020 reflect increased segment results for Gathering and Processing and Logistics and Transportation. See “Review of Segment Performance” for additional information regarding changes in operating margin and gross margin on a segment basis.

 

 


 

Depreciation and amortization expense decreased primarily due to a lower depreciable base associated with assets that were impaired during the first quarter of 2020 and the sale of the Delaware crude gathering system, which was effective December 1, 2019. The decrease in depreciation and amortization expense was partially offset by higher depreciation related to major growth capital projects placed in service, including Train 7 and the additional processing plants and associated infrastructure in the Permian Basin.

 

General and administrative expense decreased due to cost reduction measures resulting in lower non-labor expenses and reduced compensation and benefits.

 

Interest expense, net, increased due to higher average borrowings and lower capitalized interest resulting from lower growth capital investments.

 

The increase in equity earnings is primarily due to higher earnings from the Company's investments in Gulf Coast Express Pipeline LLC (“GCX”) and Little Missouri 4 LLC (“Little Missouri 4”), partially offset by lower earnings from Gulf Coast Fractionators LP (“GCF”).

 

During the three months ended June 30, 2020, the Partnership repurchased a portion of its outstanding senior notes on the open market, paying $117.7 million plus accrued interest to repurchase $140.6 million of the notes, resulting in a $21.8 million net gain from financing activities.

 

The increase in income tax benefit is primarily due to change in the valuation allowance.

 

Net income attributable to noncontrolling interests was higher in 2020 primarily due to income allocated to noncontrolling interest holders in Targa Badlands LLC (“Targa Badlands”), Targa GCX Pipeline LLC (“GCX DevCo JV”), and the Grand Prix Pipeline LLC (“Grand Prix Joint Venture”).

 

Six Months Ended June 30, 2020 Compared to Six Months Ended June 30, 2019

 

The decrease in commodity sales reflects lower NGL, natural gas, condensate, and petroleum products prices ($1,243.0 million) and lower crude marketing volumes ($131.2 million), partially offset by higher NGL, natural gas, condensate, and petroleum products volumes ($596.5 million) and the favorable impact of hedges ($174.1 million).

 

The decrease in fees from midstream services is primarily due to new transportation arrangements for Badlands volumes during the six months ended June 30, 2020, which resulted in a change from net presentation as fees from midstream services to gross presentation as sales of commodities and product purchases, partially offset by increased export volumes.

 

The decrease in product purchases reflects decreased NGL, natural gas, petroleum products and condensate prices, partially offset by increases in volumes.

 

Higher operating margin and gross margin in 2020 reflect increased segment results for Gathering and Processing and Logistics and Transportation. See “Review of Segment Performance” for additional information regarding changes in operating margin and gross margin on a segment basis.

 

Depreciation and amortization expense decreased primarily due to a lower depreciable base associated with assets that were impaired during the first quarter of 2020 and the sale of the Delaware crude gathering system, which was effective December 1, 2019. The decrease in depreciation and amortization expense was partially offset by higher depreciation related to major growth capital projects placed in service, including Train 7 and the additional processing plants and associated infrastructure in the Permian Basin.

 

General and administrative expense decreased due to cost reduction measures resulting in reduced compensation and benefits and lower non-labor expenses.

 

The impairment charge is primarily associated with the partial impairment of gas processing facilities and gathering systems in the first quarter of 2020 associated with the Company's Mid-Continent operations and full impairment of the Company’s Coastal operations - all of which are in the Company’s Gathering and Processing segment. Based on then-current market conditions, the Company’s first quarter impairment assessment projected further decline in natural gas production across the Mid-Continent and Gulf of Mexico. The Company did not recognize any impairments of long-lived assets during the first quarter of 2019. The Company may identify additional triggering events in the future, which will require additional evaluations of the recoverability of the carrying value of the Company’s long-lived assets and may result in future impairments.

 

Interest expense, net, increased due to higher average borrowings and lower capitalized interest resulting from lower growth capital investments.

 

 


 

The increase in equity earnings is primarily due to higher earnings from the Company’s investments in GCX and Little Missouri 4, partially offset by lower earnings from GCF.

 

During the six months ended June 30, 2020, the Partnership repurchased a portion of its outstanding senior notes on the open market, paying $239.8 million plus accrued interest to repurchase $303.3 million of the notes, resulting in a $61.1 million net gain from financing activities.

 

The increase in income tax benefit is primarily due to a higher pre-tax book loss and an additional benefit of net operating loss carryback from the CARES Act.

 

Net income attributable to noncontrolling interests was lower in 2020 primarily due to impairment losses allocated to noncontrolling interest holders, partially offset by income allocated to noncontrolling interest holders in Targa Badlands, GCX DevCo JV, the Grand Prix Joint Venture and Train 6.

 

Review of Segment Performance

 

The following discussion of segment performance includes inter-segment activities. The Company views segment operating margin and gross margin as important performance measures of the core profitability of its operations. These measures are key components of internal financial reporting and are reviewed for consistency and trend analysis. For a discussion of operating margin and gross margin, see “Targa Resources Corp. ― Non-GAAP Financial Measures ― Operating Margin” and “Targa Resources Corp. ― Non-GAAP Financial Measures ― Gross Margin.” Segment operating financial results and operating statistics include the effects of intersegment transactions. These intersegment transactions have been eliminated from the consolidated presentation.

The Company operates in two primary segments: (i) Gathering and Processing; and (ii) Logistics and Transportation.

 

Gathering and Processing Segment

 

The Gathering and Processing segment includes assets used in the gathering of natural gas produced from oil and gas wells and processing this raw natural gas into merchantable natural gas by extracting NGLs and removing impurities; and assets used for crude oil gathering and terminaling. The Gathering and Processing segment's assets are located in the Permian Basin of West Texas and Southeast New Mexico (including the Midland, Central and Delaware Basins); the Eagle Ford Shale in South Texas; the Barnett Shale in North Texas; the Anadarko, Ardmore, and Arkoma Basins in Oklahoma (including the SCOOP and STACK) and South Central Kansas; the Williston Basin in North Dakota (including the Bakken and Three Forks plays); and the onshore and near offshore regions of the Louisiana Gulf Coast and the Gulf of Mexico.

 


 


 

The following table provides summary data regarding results of operations of this segment for the periods indicated:

 

 

Three Months Ended June 30,

 

 

 

 

 

 

 

 

 

 

 

Six Months Ended June 30,

 

 

 

 

 

 

 

 

 

 

 

2020

 

 

2019

 

 

2020 vs. 2019

 

 

2020

 

 

2019

 

 

2020 vs. 2019

 

 

(In millions, except operating statistics and price amounts)

 

Gross margin

$

 

338.3

 

 

$

 

363.8

 

 

$

 

(25.5

)

 

 

(7

%)

 

$

 

708.7

 

 

$

 

725.1

 

 

$

 

(16.4

)

 

 

(2

%)

Operating expenses

 

 

101.1

 

 

 

 

131.7

 

 

 

 

(30.6

)

 

 

(23

%)

 

 

 

215.9

 

 

 

 

254.8

 

 

 

 

(38.9

)

 

 

(15

%)

Operating margin

$

 

237.2

 

 

$

 

232.1

 

 

$

 

5.1

 

 

 

2

%

 

$

 

492.8

 

 

$

 

470.3

 

 

$

 

22.5

 

 

 

5

%

Operating statistics (1):

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Plant natural gas inlet, MMcf/d (2),(3)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Permian Midland (4)

 

 

1,698.9

 

 

 

 

1,425.3

 

 

 

 

273.6

 

 

 

19

%

 

 

 

1,677.0

 

 

 

 

1,374.2

 

 

 

 

302.8

 

 

 

22

%

Permian Delaware

 

 

651.6

 

 

 

 

545.1

 

 

 

 

106.5

 

 

 

20

%

 

 

 

689.3

 

 

 

 

513.0

 

 

 

 

176.3

 

 

 

34

%

Total Permian

 

 

2,350.5

 

 

 

 

1,970.4

 

 

 

 

380.1

 

 

 

 

 

 

 

 

2,366.3

 

 

 

 

1,887.2

 

 

 

 

479.1

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

SouthTX (5)

 

 

265.1

 

 

 

 

313.8

 

 

 

 

(48.7

)

 

 

(16

%)

 

 

 

275.7

 

 

 

 

338.7

 

 

 

 

(63.0

)

 

 

(19

%)

North Texas

 

 

197.8

 

 

 

 

224.0

 

 

 

 

(26.2

)

 

 

(12

%)

 

 

 

210.6

 

 

 

 

227.2

 

 

 

 

(16.6

)

 

 

(7

%)

SouthOK (6)

 

 

439.8

 

 

 

 

607.7

 

 

 

 

(167.9

)

 

 

(28

%)

 

 

 

501.9

 

 

 

 

613.8

 

 

 

 

(111.9

)

 

 

(18

%)

WestOK

 

 

251.2

 

 

 

 

338.2

 

 

 

 

(87.0

)

 

 

(26

%)

 

 

 

271.4

 

 

 

 

338.2

 

 

 

 

(66.8

)

 

 

(20

%)

Total Central

 

 

1,153.9

 

 

 

 

1,483.7

 

 

 

 

(329.8

)

 

 

 

 

 

 

 

1,259.6

 

 

 

 

1,517.9

 

 

 

 

(258.3

)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Badlands (7),(8)

 

 

111.6

 

 

 

 

92.3

 

 

 

 

19.3

 

 

 

21

%

 

 

 

135.6

 

 

 

 

94.6

 

 

 

 

41.0

 

 

 

43

%

Total Field

 

 

3,616.0

 

 

 

 

3,546.4

 

 

 

 

69.6

 

 

 

 

 

 

 

 

3,761.5

 

 

 

 

3,499.7

 

 

 

 

261.8

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Coastal

 

 

713.0

 

 

 

 

804.9

 

 

 

 

(91.9

)

 

 

(11

%)

 

 

 

748.8

 

 

 

 

787.5

 

 

 

 

(38.7

)

 

 

(5

%)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Total

 

 

4,329.0

 

 

 

 

4,351.3

 

 

 

 

(22.3

)

 

 

(1

%)

 

 

 

4,510.3

 

 

 

 

4,287.2

 

 

 

 

223.1

 

 

 

5

%

NGL production, MBbl/d (3)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Permian Midland (4)

 

 

245.0

 

 

 

 

198.0

 

 

 

 

47.0

 

 

 

24

%

 

 

 

245.0

 

 

 

 

191.3

 

 

 

 

53.7

 

 

 

28

%

Permian Delaware

 

 

89.6

 

 

 

 

71.4

 

 

 

 

18.2

 

 

 

25

%

 

 

 

93.0

 

 

 

 

65.9

 

 

 

 

27.1

 

 

 

41

%

Total Permian

 

 

334.6

 

 

 

 

269.4

 

 

 

 

65.2

 

 

 

 

 

 

 

 

338.0

 

 

 

 

257.2

 

 

 

 

80.8

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

SouthTX (5)

 

 

28.8

 

 

 

 

41.7

 

 

 

 

(12.9

)

 

 

(31

%)

 

 

 

28.5

 

 

 

 

45.2

 

 

 

 

(16.7

)

 

 

(37

%)

North Texas

 

 

23.5

 

 

 

 

26.6

 

 

 

 

(3.1

)

 

 

(12

%)

 

 

 

24.9

 

 

 

 

26.7

 

 

 

 

(1.8

)

 

 

(7

%)

SouthOK (6)

 

 

51.3

 

 

 

 

68.3

 

 

 

 

(17.0

)

 

 

(25

%)

 

 

 

59.0

 

 

 

 

63.3

 

 

 

 

(4.3

)

 

 

(7

%)

WestOK

 

 

21.0

 

 

 

 

23.8

 

 

 

 

(2.8

)

 

 

(12

%)

 

 

 

22.1

 

 

 

 

24.0

 

 

 

 

(1.9

)

 

 

(8

%)

Total Central

 

 

124.6

 

 

 

 

160.4

 

 

 

 

(35.8

)

 

 

 

 

 

 

 

134.5

 

 

 

 

159.2

 

 

 

 

(24.7

)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Badlands (8)

 

 

13.9

 

 

 

 

11.3

 

 

 

 

2.6

 

 

 

23

%

 

 

 

16.0

 

 

 

 

11.3

 

 

 

 

4.7

 

 

 

42

%

Total Field

 

 

473.1

 

 

 

 

441.1

 

 

 

 

32.0

 

 

 

 

 

 

 

 

488.5

 

 

 

 

427.7

 

 

 

 

60.8

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Coastal

 

 

43.2

 

 

 

 

47.3

 

 

 

 

(4.1

)

 

 

(9

%)

 

 

 

46.0

 

 

 

 

47.8

 

 

 

 

(1.8

)

 

 

(4

%)