Enterprise Products Partners L.P.

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EPD

US2937921078

Oil & Gas Transportation Services

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Products Partners L P : 4Q 2019 Earnings Support Slides

January 30, 2020 at 07:20 am EST

ENTERPRISE PRODUCTS PARTNERS L.P.

FOURTH QUARTER 2019

EARNINGS SUPPORT SLIDES

enterpriseproducts.com

QUALIFYING STATEMENTS

This supplemental package of earnings support slides provides highlights of major variances for the quarter.

This data should be read in conjunction with the information contained in the earnings release for the fourth quarter of 2019, which provides a more comprehensive description of the changes between the relevant periods.

FORWARD-LOOKING STATEMENTS

This presentation contains forward-looking statements based on the beliefs of the company, as well as assumptions made by, and information currently available to our management team. When used in this presentation, words such as "anticipate," "project," "expect," "plan," "seek," "goal," "estimate," "forecast," "intend," "could," "should," "will," "believe," "may," "scheduled," "potential" and similar expressions and statements regarding our plans and objectives for future operations, are intended to identify forward-looking statements.

Although management believes that the expectations reflected in such forward-looking statements are reasonable, it can give no assurance that such expectations will prove to be correct. You should not put undue reliance on any forward-looking statements, which speak only as of their dates. Forward-looking statements are subject to risks and uncertainties that may cause actual results to differ materially from those expected, including insufficient cash from operations, adverse market conditions, governmental regulations, the possibility that tax or other costs or difficulties related thereto will be greater than expected, the impact of competition and other risk factors discussed in our latest filings with the Securities and Exchange Commission.

All forward-looking statements attributable to Enterprise or any person acting on our behalf are expressly qualified in their entirety by the cautionary statements contained herein, in such filings and in our future periodic reports filed with the Securities and Exchange Commission. Except as required by law, we do not intend to update or revise our forward-looking statements, whether as a result of new information, future events or otherwise.

LIQUIDITY OPTION AGREEMENT

Put Option Resulting from the Oiltanking Acquisition

Enterprise Products

Partners L.P.

"EPD"

New units	Marquard & Bahls AG
and/or cash

100% Common	"M&B"
Stock of OTA

Oiltanking Holdings

Americas Inc.

"OTA"

54.8MM EPD Units ≈$500MM Deferred Tax Liability

M&B option to put to us 100% of common stock of OTA within a 90-day period commencing February 1, 2020 If exercised, EPD would own OTA and indirectly assume deferred tax liability of OTA

Unit treatment: the 54.8MM units owned by OTA would be treated as EPD treasury units for GAAP purposes
Taxes: OTA's tax liability would show as a deferred tax on EPD's balance sheet until cash taxes become payable, including if we ever sold the 54.8MM units
- We expect there will be minimal tax leakage from owning a C-Corp, based on its ownership of the EPD units and its allocable share of income (less than $25MM/year)

We have the option to either satisfy M&B's exercise with newly issued units or cash, or any combination thereof

If satisfied with newly issued units, it would be neutral to unit count publicly traded (through GAAP elimination)
If satisfied with cash, it would reduce outstanding units for GAAP purposes (similar to a buyback)

CAPITAL ALLOCATION TRENDS ACROSS SECTORS

Relative to 9 Months Ended September 2019

Real Estate

Industrials Information Technology

OFS(4)

Enterprise Products Consumer Discretionary

Midstream (1)

S&P 500(3)

Consumer Staples

Materials

Health Care

Energy

Utilities

E&P (2)

Communication Services

			Capex		Dividends / Distributions		Equity Repurchase
		as % of Trailing 9 Months Cash flow from Operations

			90%							71%
	64%				27%				41%		132%
34%		20%			45%		99%
			86%					36%			27%	149%
	58%				59%				2%	119%
	40%			22%	36%		99%
			97%							51%			148%
	45%			22%	24%		91%
	41%			30%	16%	86%
	53%		21%	18%		91%
	38%		7%	28%	74%
			102%			14%	13%	129%
			101%					24%		125%
				110%					6%	9%	126%
20%	6%0%27%
	20%		40%	60%	80%		100%		120%	140%	160%

Payout/CFFO	Ranked Payout
71%	1
68%	2
65%	3
63%	4
61%	5
59%	6
51%	7
45%	8
45%	9
38%	10
36%	11
26%	12
24%	13
15%	14
6%	15

Sources: Bloomberg as of January 3,2019 for the 9 months ended, September 2019, Consensus estimates; Median value of S&P 500 firms; Payout consists of indicated dividends defined as most recent dividend and common stock repurchases of first 3 Quarters of 2019; 1 Median figures for Kinder Morgan (KMI), ONEOK (OKE), and Williams Companies (WMB); 2 Median figures for Hess Corp (HES), Apache Corp (APA), Cabot Oil & Gas Corp (COG), Eog Resources Inc (EOG), Devon Energy Corp (DVN), Noble Energy Inc (NBL), ConocoPhillips (COP), Pioneer Natural Resources Co (PXD), Marathon Oil Corp (MRO), Cimarex Energy Co (XEC), Concho Resources Inc. (CXO); 3 Median excludes Financials and Real Estate; 4 Median figures of TechnipFMC (FTI), Halliburton (HAL), National Oilwell (NOV), Schlumberger (SLB) and Baker Hughes (BHGE);

INDICATIVE ATTRIBUTION OF GROSS

OPERATING MARGIN

Slides 8-10 attribute gross operating margin (GOM) among fee-based,commodity-based and differential- based business activities. Most activities fit easily into one category; however, the classification of certain activities involves an element of subjectivity. The classifications reflected in the following slides represent what we currently believe is the most logical fit of our business activities into the categories described below, based on the underlying fee or pricing characteristics applicable thereto.

These classifications may be subject to change in the event that management's estimates or assumptions underlying such classifications are revised or updated. In addition, our attribution of GOM into the categories described below may not be comparable to similar classifications by other companies because such companies may use different estimates and assumptions than we do in defining such categories or otherwise calculating such attributions.

Three categories of GOM:

Fee-based: Pipeline transportation fees and tariffs, NGL and propylene fractionation fees, storage capacity reservation and throughput fees, export terminal fees, marine and trucking fees, fee-based natural gas processing arrangements, isomerization and dehydrogenation fees, demand and deficiency fees, and similar activities that are predominantly fee-oriented.
Commodity-based:Percentage-of-liquids and percentage-of-proceeds natural gas processing arrangements, certain condensate sales, gathering revenues on our San Juan natural gas pipeline system, and similar activities that have commodity price exposure.
Differential-based: Certain business activities where earnings are generated based on price differentials or spreads between locations, time periods and products in excess of any related fees, tariffs and other expenses.

GROSS OPERATING MARGIN BRIDGE

4Q 2019 vs. 4Q 2018

4Q 2018

Non-Cash

New &

Existing Assets

Legacy Gas

Marketing

4Q 2019

3Q 2019

Non-Cash

New &

Existing Assets

Legacy Gas

Marketing

4Q 2019

GOM

MTM Change

Expanded

with Operating

Plants

(excl. MTM) &

GOM

MTM Change

Expanded

with Operating

Plants

(excl. MTM) &

GOM

Assets

Leverage

Other Changes

Assets

Leverage

Other Changes

Details:

Non-cashmark-to-market ("MTM") changes are a function of the hedging of crude oil, natural gas and natural gas liquids ("NGL") price differentials between regional markets; this hedging is associated with marketing activities related to certain pipeline capacity

4Q 2019 was a loss of ($25MM), 4Q 2018 was a gain of $239MM, and 3Q 2019 was a gain of $9MM

New and expanded assets are those which have been placed in-service or expanded in the past 12 months; these include Shin Oak NGL pipeline, Aegis pipeline expansion, Orla gas processing trains & related gathering, LPG export capacity expansion, Midland-to-ECHO 2 pipeline and the Seaway crude pipeline expansion, among others

Existing assets (excluding natural gas processing plants) with operating leverage that increased >$1MM vs. comparable period and did not have a contractual ramp or expansion

Indicative processing spreads (Mont Belvieu NGL vs. Henry Hub natural gas) were $0.25/gal for 4Q 2019 vs. $0.34 & $0.21 for 4Q 2018 & 3Q 2019, respectively

Total gross operating margin is a Non-GAAP measure. For a reconciliation of these amounts to their nearest GAAP counterparts, see "Non-GAAP Financial Measures" on our website.
© ALL RIGHTS RESERVED. ENTERPRISE PRODUCTS PARTNERS L.P.	7

INDICATIVE ATTRIBUTION OF GROSS OPERATING MARGIN

Gross Operating Margin in $Billions

$9.0

$8.0

$7.0

$6.0

$5.0

$4.0

$3.0

$2.0

$1.0

$0.0

			$8.3B
		$7.3B	10%
		8%	4%
		$7.1B
		6%
	$5.7B
$5.2B		14%
6%
	growth in
5%	5%
4%			fee-based
			GOM $
		86%	86%
	89%	fee-based
91%	fee-based

fee-basedfee-based

2016	2017	2018	2019
Fee-Based	Commodity Price-Based		Differential-Based

Total gross operating margin is a Non-GAAP measure. For a reconciliation of these amounts to their nearest GAAP counterparts, see "Non-GAAP Financial Measures" on our website.

INDICATIVE ATTRIBUTION OF SEGMENT GOM FOR 2019

% Breakout of GOM

100%

80%

60%

40%

20%

	2%
11%	7%	16%	12%

2%	5%

	10%

87%	91%		83%
fee-based	74%
fee-based	fee-based
		fee-based

NGL Segment(1)Crude Segment Natural Gas Segment(2) Petchem & Refined(3) Products Segment

Fee-Based Commodity Price-BasedDifferential-Based

Based on Gross Operating Margin

Percentage of liquids and percentage of proceeds agreements are considered commodity-based; keepwhole agreements are differential based
San Juan gathering generates commodity sensitive earnings, while natural gas marketing includes Waha to Carthage and Waha to Houston transportation differentials
Largest differential contribution was from propylene fractionation and refined products marketing

Total gross operating margin is a Non-GAAP measure. For a reconciliation of these amounts to their nearest GAAP counterparts, see "Non-GAAP Financial Measures" on our website.

INDICATIVE ATTRIBUTION OF GOM FOR SELECT BUSINESSES

Natural Gas Processing GOM

	$600			$500		$0.50
		Mostly Pioneer,

		Meeker and				$0.40
SMillions	$400	South Texas
			$356	$0.30	Spread

		$244
GOM in					$0.20	Price
$200	$169

			57%	70%	$0.10

		81%	68%


	$0					$0.00
		2016	2017	2018	2019
	Fee	Keepwhole	POP & POL	Indicative Processing Spreads ($/Gal)

Propylene Activities GOM & Related Spreads

Octane Enhancement / HPIB GOM & Related Spreads

	$500	Largely propylene	$463	$445	$0.80			$180

		sales during PDH		$0.70			$160
	$400		startup
					$0.60			$140

$Millions							$Millions
$300					$0.50	Spread	$120
				$100

		$222			$0.40
	$212			$80
GOM in	$200			$0.30	Price	GOM in
		74%	79%	$60


					$0.20
	$100							$40
	70%	69%
			$0.10
						$20

	$0					$0.00			$0
		2016	2017	2018	2019
		Fee	Non-Fee	Spread PGP vs RGP ($/Gal)

			$166	$1.20
		$154
			$1.00

	$123			$0.80
				Spread
				$0.60
MTBE Plant				Price

Turnaround				$0.40

$42		61%	62%
55%
			$0.20
60%				$0.00

2016	2017	2018	2019
Fee	Non-Fee	Spread RBOB vs Butane ($/Gal)
					10

SEGMENT GROSS OPERATING MARGIN VARIANCE

4Q 2019 VS. 4Q 2018

enterpriseproducts.com

NGL SEGMENT

GOM BRIDGE 4Q 2019 VS. 4Q 2018

$ in MMs

($1)

4Q 2018

Non-Cash

Shin Oak,

Aegis

EHT LPG

MTBV

NGL

MAPL &

Legacy Gas

Marketing

Other

4Q 2019

GOM

MTM

Seminole &

Pipeline

Terminal

Storage

Fracs

Chaparral

Plants

(excl. MTM)

GOM

Details:

Change

Related P/Ls

Non-cash MTM activity resulted in a loss of ($5MM) in 4Q 2019 compared to a gain of $10MM in 4Q 2018

Shin Oak began commercial service with limited capacity in 1Q 2019; the final capacity expansion to 550 MBPD was completed in 4Q 2019 Aegis pipeline increased primarily due to higher transportation volume from new cracker demand

EHT LPG loading volume increased 141 MBPD primarily due to the dock expansion completed in late 3Q 2019

Mont Belvieu storage benefited from higher revenues associated with throughput fees, Y-grade handling fees and storage fees NGL fractionation volumes increased primarily due to a turnaround at our Mont Belvieu complex in 4Q 2018

Legacy gas plants decreased due to lower average processing margins despite an increase in total fee-based processing volumes Marketing (excluding MTM) increased primarily due to higher sales volumes and average margins in part due to the LPG export expansion

CRUDE OIL SEGMENT

GOM BRIDGE 4Q 2019 VS. 4Q 2018

$ in MMs

($15)

4Q 2018	Non-Cash	EHT	WTX, STX &	Seaway	Marketing	Other	4Q 2019
GOM	MTM	Crude Oil	Permian		(excl. MTM		GOM
	Change		to Houston P/Ls		& M2E1)

Details:

Non-cash MTM activity resulted in a loss of ($15MM) in 4Q 2019 compared to a gain of $223MM in 4Q 2018

EHT crude loading volumes increased 221 MBPD compared to 4Q 2018, this was partially offset by a 22 MBPD decrease in unloading volumes

WTX, STX and Permian to Houston P/Ls increased primarily due to the Midland-to-ECHO 2 (Seminole conversion) which came on-line in 2Q 2019 contributing $27MM

Seaway increased primarily due to higher average transportation fees and lower operating expenses

Other marketing (excluding non-cash MTM and Midland-to-ECHO 1) decreased primarily due to lower sales margins

NATURAL GAS SEGMENT

GOM BRIDGE 4Q 2019 VS. 4Q 2018

$ in MMs

	4Q 2018	Non-Cash	Permian	TX	Haynesville	Acadian	Rockies &	Marketing	Other	4Q 2019
	GOM	MTM	Gathering	Intrastate	Gathering	Gas System	San Juan	(excl. MTM)		GOM
Details:	Change					Gathering

Non-cash MTM activity resulted in a loss of ($0.1MM) in 4Q 2019 compared to a gain of $4MM in 4Q 2018

Permian gathering increased primarily due to a 285 BBtus/d increase in volumes

Texas intrastate decreased primarily due to lower capacity reservation fees

Haynesville gathering decreased primarily due to lower average fees and a 138 BBtus/d decrease in volumes

Acadian gas system decreased primarily due to lower capacity reservation fees

Rockies and San Juan decreased primarily due to a combined 384 BBtus/d decrease in gathering volumes

Marketing (excluding MTM) decreased primarily due to lower volumes

PETROCHEMICAL AND REFINED PRODUCTS GOM BRIDGE 4Q 2019 VS. 4Q 2018

$ in MMs

4Q 2018	Non-Cash	HPIB Plant	MTBV Isoms	PDH Facility	Octane	Other	4Q 2019
GOM	MTM	& Terminal			Enhancement		GOM
	Change				Facility

Details:

Non-cash MTM activity resulted in a loss of ($4MM) in 4Q 2019 compared to a gain of $3MM in 4Q 2018 The HPIB facility increased primarily due to lower operating costs; the facility had a turnaround in 4Q 2018 The Mont Belvieu Isoms increased primarily due to higher average by-product sales prices

The PDH facility decreased primarily due to 30 days of downtime for unplanned maintenance during 4Q 2019 Octane enhancement facility decreased primarily due to 21 days of downtime for maintenance during 4Q 2019

SEGMENT GROSS OPERATING MARGIN VARIANCE

4Q 2019 VS. 3Q 2019

enterpriseproducts.com

NGL SEGMENT

GOM BRIDGE 4Q 2019 VS. 3Q 2019

$ in MMs

3Q 2019	Non-Cash	NGL	MAPL &	EHT LPG	Dixie &	MTBV	Legacy Gas	Other	4Q 2019
GOM	MTM change	Marketing	Related	Terminal	Related	Fractionation	Plants		GOM
		(excl. MTM)	Terminals		Terminals	Complex

Details:

Non-cash MTM activity resulted in a loss of ($5MM) in 4Q 2019 compared to a loss of ($1MM) in 3Q 2019 Marketing (excluding MTM) benefitted from the LPG export capacity expansion at EHT and storage optimization MAPL and related terminals benefitted from increased volumes related to seasonality

EHT increased 128 MBPD due to the LPG export capacity expansion which ramped up during 4Q 2019 Dixie and related terminals benefitted from increased volumes related to seasonality

Mont Belvieu fractionators increased due to a net volume increase of 23 MBPD

Legacy gas plants decreased primarily due to lower processing margins related to incremental ethane extraction

CRUDE OIL SEGMENT

GOM BRIDGE 4Q 2019 VS. 3Q 2019

$ in MMs

3Q 2019	Non-Cash MTM	Midland-to-	EHT Crude	Eagle Ford (JV)	Seaway (JV)	Other	4Q 2019
GOM	Change	ECHO 1, incl.	Terminal	Pipeline &	Pipeline		GOM
		Marketing		Terminal

Details:

(excl. MTM)

Non-cash MTM activity resulted in a loss of ($14MM) in 4Q 2019 compared to a gain of $10MM in 3Q 2019 Midland-to-ECHO 1 decreased due to lower earnings from marketing activities

EHT crude terminal decreased in part due to a 26 MBPD decrease in volumes loaded for exports Eagle Ford pipeline and terminal decreased due to a 9 MBPD decrease in pipeline volumes

Seaway pipeline decreased due to 24 MBPD decrease in pipeline volumes and 10 MBPD decrease in volumes loaded for export

NATURAL GAS SEGMENT

GOM BRIDGE 4Q 2019 VS. 3Q 2019

$ in MMs

3Q 2019	Non-Cash	BTA Gathering	Marketing	Acadian Gas	Other	4Q 2019
GOM	MTM Change		(excl. MTM)	System		GOM

Details:

BTA Gathering increased due to a 14 Bbtu/d increase in gathering volume Marketing activity declined due to lower sales volumes across Texas

Acadian gas system decreased primarily due to a legal settlement which was recognized as benefit in 3Q 2019

PETROCHEMICAL AND REFINED PRODUCTS GOM BRIDGE 4Q 2019 VS. 3Q 2019

$ in MMs

3Q 2019	Non-Cash	TE Products	Octane	PDH	Mont Belvieu	Other	4Q 2019
GOM	MTM Change	Pipeline	Enhancement	Facility	Propylene		GOM
			Facility		Splitters

Details:

TE Products pipeline benefitted from higher deficiency fees and higher transportation volumes largely due to seasonality Octane enhancement facility decreased due to 21 days of downtime for maintenance in 4Q 2019

PDH facility decreased primarily due to 30 days of unplanned maintenance during 4Q 2019 Mont Belvieu propylene splitters decreased due to lower sales margins and volumes

WE CONTINUE TO INVEST AND GROW

≈$7.7B* of Major Capital Projects Under Construction

Midland-to-ECHO 2 LPG Dock Expansion

NatGas

EHT LPG & PGP

$6.0

Shin Oak NGL P/L iBDH Plant

Ethylene Export Terminal

Orla 3, Mentone & Panola III Gas Plants EHT 58 acres expansion

10%

Petchem

& RP

NGLs 20%

Expansion

C5 Hydrotreater

Midland-to-ECHO 4

Isom MTBV Area

DIB 3 MTBV Area

$5.0

$5.4

40%Crude

30%

PDH2

$4.6

$ in Billions

$4.0

$3.0

$2.0

$1.0

$0.0

Midland-to-ECHO 3

EHT Dock 1A Layberth

Frac 11 MTBV Area

DIB 2 MTBV Area

Frac 10
MTBV Area	TX Express & Front Range
Permian	Expansions (1H20)
Gathering	EFS Projects	$1.7
Projects	Other Tank Projects

$0.5

EHT Dock 1A

Expansion

Ethylene Export

Expansion & P/Ls

$0.8

2019 Total	1Q 2020	2Q 2020	3Q 2020	4Q 2020	2021-2023 Total
Note to Title: * Does not include Sea Port Oil Terminal ("SPOT")		Estimated

Note to Body: Callout boxes contain a selection of highlighted projects, and may not represent the entirety of projects included in the monetary sums
© ALL RIGHTS RESERVED. ENTERPRISE PRODUCTS PARTNERS L.P.					21

GROWTH CAPITAL PROJECTS

Completed in 2019
Under Construction (1Q20-Forward)

Highlighted Capital Projects

Orla III Gas Processing Plant

Liquids	Shoup Frac Optimization
EHT LPG Export Expansion
(Metering)

Gas	Shin Oak 24" Pipeline

Natural	Mentone Gas Processing Plant &

	Related Pipelines
	Panola III ("Bulldog") Gas Processing
	Plant & Related Pipelines

Natural Gas	North TX 36" JV Pipeline Expansion
Sand Dunes Gathering System
	Midland-to-ECHO 2 (M2E2)
	Seminole Conversion
Crude	Midland & Sealy Tank Expansions
EHT 58 Acre Phase 2 & "Tank 9"

	Expansions
	Eagle Ford JV - Corpus Christi Dock
Petchem& RefinedProducts	Beaumont Refined Products
("iBDH") Plant
	Buildout
	Ethylene Export Terminal, Pipeline
	& Well Conversion
	Isobutane Dehydrogenation

Total Placed In-Service in 2019 ($ Billions)

In-Service

2Q 2019

3Q 2019

1Q 2019 &

4Q 2019

1Q 2019

4Q 2019

2Q 2019

3Q 2019

2Q 2019 &

4Q 2019

3Q 2019

4Q 2019

$5.4

	Highlighted Major Capital Projects	Fcst In-Service	1Q 20 2Q 20 3Q 20 4Q 20 2021+
Liquids	Mont Belvieu Area Fractionators 10 & 11	1Q 2020 &	√		√
3Q 2020


Gas	Texas Express & Front Range Expansions	1H 2020		√
EHT LPG & PGP Export Expansion (Refrigeration)	*2021+
Natural					√

C5 Hydrotreater	3Q 2021					√

Natural Gas	Natural Gas Pipeline to Carthage (Panola related)	3Q 2020			√
Gillis Lateral & Acadian Haynesville Expansion	3Q 2021					√


	Permian Gathering & Residue Lines	*2021+					√

	Permian Gathering & Condensate Projects	1Q 2020	√
Oil	Midland-to-ECHO 3 Pipeline	3Q 2020			√

EHT Dock 1A Layberth & Expansion	3Q-4Q 2020			√	√
Crude
EFS Projects & Other Tank Projects	2Q 2020		√		√


	Midland & ECHO Tank Expansions (Support M2E3)	1Q 2021					√

	Midland-to-ECHO 4 Pipeline	2Q 2021					√

Petrochemical& RefinedProducts	PDH 2 Facility	3Q 2020 &			√		√
1Q 2023
	Mont Belvieu Area DIB 2 & 3	1Q 2022				√
	Mont Belvieu Area Isom	1Q 2022					√
	Ethylene Export Expansion (Tank) & Ethylene Pipelines	4Q 2020				√

	Total Major Capital In-Service Forecast ($ Billions) $0.5	$0.2	$1.7	$0.8	$4.6

Note: The tables above include a selection of highlighted projects, and may not represent the entirety of projects included in the	*In-Service date subject to final engineering schedule
monetary sums	22
© ALL RIGHTS RESERVED. ENTERPRISE PRODUCTS PARTNERS L.P.

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Enterprise Products Partners LP published this content on 30 January 2020 and is solely responsible for the information contained therein. Distributed by Public, unedited and unaltered, on 30 January 2020 12:19:07 UTC

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Company Profile

Enterprise Products Partners L.P. provides midstream energy services to producers and consumers of natural gas, natural gas liquids (NGLs), crude oil, petrochemicals and refined products. Its NGL Pipelines & Services segment includes natural gas processing and related NGL marketing activities, NGL pipelines, NGL fractionation facilities, NGL and related product storage facilities and NGL marine terminals. Its Crude Oil Pipelines & Services segment includes crude oil pipelines, crude oil storage and marine terminals and related crude oil marketing activities. Its Natural Gas Pipelines & Services segment includes natural gas pipeline systems that provide for the gathering, treating and transportation of natural gas. Its Petrochemical & Refined Products Services segment includes propylene production facilities, butane isomerization complex and related deisobutanizer operations and others. It also owns 20% interest in Whitethorn and has two NGL fractionators located in Mont Belvieu, Texas.

Sector

Oil & Gas Transportation Services

Calendar

2024-04-28 - Ex-dividend day

More about the company

Income Statement Evolution

More financial data

Analysis / Opinion

Enterprise Products Partners in the shadow of US oil mega-mergers

February 20, 2024 at 05:22 am EST

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Ratings for Enterprise Products Partners L.P.

Trading Rating

Investor Rating

ESG Refinitiv

C+

More Ratings

Analysts' Consensus

Sell

Buy

Mean consensus

BUY

Number of Analysts

Last Close Price

28.44 USD

Average target price

32.49 USD

Spread / Average Target

+14.23%

Consensus

EPS Revisions

Estimates Revisions

Quarterly earnings - Rate of surprise

Company calendar

Sector Other Oil & Gas Transportation Services

	1st Jan change	Capi.
ENTERPRISE PRODUCTS PARTNERS L.P.	+7.93%	61.66B
ENBRIDGE INC.	-2.16%	72.15B
WILLIAMS COMPANIES	+7.90%	45.79B
ONEOK, INC..	+10.91%	45.45B
MPLX LP	+9.50%	40.64B
KINDER MORGAN, INC.	+3.23%	40.41B
TC ENERGY CORPORATION	-6.22%	36.63B
TARGA RESOURCES CORP.	+28.68%	24.87B
CHENIERE ENERGY PARTNERS, L.P.	-2.11%	23.59B
PEMBINA PIPELINE CORPORATION	+3.46%	19.89B

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