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Member SIPC
IPAA Leaders in Industry LuncheonUpstream Deal Flow Environment – Past, Present and FutureAre Those Green Shoots Growing or Weeds?
January 11, 2017
William A. Marko Managing DirectorJefferies LLC
Jefferies Energy Group - 2016 Completed M&A
(1) Source: PLS. League tables include transactions since January 1, 2016 with announced sellside advisors. For transactions with more than one advisor, the total transaction value was assigned equally to each advisor.(2) Source: PLS. League tables include transactions since January 1, 2010 with announced sellside advisors. For transactions with more than one advisor, the total transaction value was assigned equally to each advisor.
September 2016
$2,000,000,000
Purchase of GOM assets fromFreeport McMoRan
Sole Financial Advisor
August 2016
$980,000,000
Sale of Midland Basin assets toSM Energy Company
Lead Financial Advisor
October 2016Pending
$1,600,000,000
Sale of Midland Basin assets toSM Energy Company
Sole Financial Advisor
October 2016Pending
$2,400,000,000
Sale of Delaware Basin assets toRSP Permian, Inc.
Sole Financial Advisor
May 2016
$407,000,000
Sale of West Virginia assets toEQT Corporation
Sole Financial Advisor
April 2016
$303,000,000Acquisition of Midland Basin assets
FromBig Star Oil and Gas, LLC
Financial Advisor
June 2016
$888,000,000
Sale of STACK assets toMarathon Oil Corporation
Sole Financial Advisor
June 2016
$1,832,000,000
Sale of Various N. American assets toUndisclosed Buyers
Lead Financial Advisor
February 2016
$385,000,000Acquisition of Western Anadarko
assets fromChesapeake Exploration, LLC
Sole Financial Advisor
April 2016
$200,000,000
Sale of Mississippian assets toWhite Star Petroleum, LLC
Lead Financial Advisor
March 2016
$420,000,000Sale of Haynesville and Bossier
assets toCovey Park Energy
Sole Financial Advisor
December 2016Pending
$915,000,000
Sale of Haynesville assets toUndisclosed Buyers
Sole Financial Advisor
December 2016Pending
$2,428,000,000
Sale of Delaware Basin assets toDiamondback Energy, Inc.
Sole Financial Advisor
December 2016Pending
$1,850,000,000
Sale of SCOOP assets toGulfport Energy Corporation
Sole Financial Advisor
December 2016Pending
$1,240,000,000
Sale of Marcellus Shale assets toAlta Marcellus Development
Sole Financial Advisor
1
The two key drivers for future energy use
GDP per capita expected to triple in China and India
─ 50% of worldwide growth in energy
─ India expected to pass China in population by 2040 (1.6 billion people)
Other key energy growth economies which will drive 30% of energy growth
─ GDP per capita is expected to double in these countries
According to Brookings Institute, number of people considered middle class will rise from 2 billion in 2014 to 5 billion in 2030, with most of the growth in India and China
Natural gas is the largest growing energy supply, increasing 40%
- Brazil - Egypt - Indonesia - Iran - Mexico
- Nigeria - Saudi Arabia - South Africa - Thailand - Turkey
Worldwide Energy DemandChina and India and Other Energy Emerging Economies
2
Massive Economic Growth Drives Increased Need for Energy
Source: ExxonMobil - The Outlook for Energy: A View to 2040
GDPTrillion 2010$
Energy DemandQuadrillion BTUs
Fortunately, Energy Efficiency Vastly Lowers Energy Use Per GDP
3
North America Swings to a Net Exporter as Shale Growth Continues
Source: ExxonMobil - The Outlook for Energy: A View to 2040
4
By 2040, Unconventional Gas Will Account for About 1/3rd of Global Gas
Source: ExxonMobil - The Outlook for Energy: A View to 2040
5
Oil Remains the World’s Top Fuel, But Natural Gas Grows the Most
Global Fuel Demand in 2040 – ProjectionsQuadrillion BTUs
Source: ExxonMobil - The Outlook for Energy: A View to 2040
6
Current Market Overview
The M&A market has seen significant improvement recently
─ $50 / Bbl oil and $3 / MMBtu gas price is a healthy capitulation point for buyers and sellers─ Large scale deals have recently been done which fit one of three themes:
1. Growth acquisitions in existing core areas with equity component and / or overnight equity raise
2. Strategic acquisitions in new core area to build diversification
3. Private capital backed major initial or follow on acquisition
─ Non-core asset sales continuing, increasing supply of asset sales in a number of plays / basins
Financial markets showed a material improvement in 2016
─ Yields have tightened considerably since the Q1 2016 trough; High yield markets are open for business – recent issuances have priced at attractive yields
─ Public E&P equity indices are up over 50% from February lows Robust demand in the equity markets; most active new issue market since Q1 2015 More aggressive deals in terms of use of proceeds and market cap have recently priced
Private capital markets are still active and remain a primary source of transaction financing─ The universe of private capital providers is expanding; abundance of capital ready to be deployed in the
space─ There is still “$100 billion” in private capital seeking energy deals
Private capital continues to increase its flexibility in terms of geography, deal structure, terms, and other aspects
7
$1.00
$1.50
$2.00
$2.50
$3.00
$3.50
$4.00
Jan-16 Feb-16 Mar-16 Apr-16 May-16 Jun-16 Jul-16 Aug-16 Sep-16 Oct-16 Nov-16 Dec-16 Jan-17
Gas
Pri
ce (
$/M
MB
tu)
Spot 3 Year Fwd
$20.00
$30.00
$40.00
$50.00
$60.00
Jan-16 Feb-16 Mar-16 Apr-16 May-16 Jun-16 Jul-16 Aug-16 Sep-16 Oct-16 Nov-16 Dec-16 Jan-17
Oil
Price
($/B
bl)
Spot 3 Year Fwd
Historical NYMEX Oil Prices ($ / Bbl)
$55.33
$52.33
Historical NYMEX Natural Gas Prices ($ / MMBtu)
Improvement in Commodity Prices Driving E&P Momentum
Source: Bloomberg as of 1/03/2017.
$3.39
$3.08
8
M&A Market Activity Continues to Accelerate – How About Q4 2016!
Date Buyer Seller Amount ($MM) Location
1/3/17 $800 Eagle Ford
12/21/16 $1,450 Marcellus Shale
12/14/16 $1,850 SCOOP / STACK
12/14/16 $2,400 Delaware Basin
12/13/16 $615 Delaware Basin
12/12/16 $292 Bakken
12/5/2016 Undisclosed $450 North Louisiana
11/21/2016 Endurance Resources $430 Delaware Basin
11/8/2016 $299 Midland Basin
10/31/2016 J. Cleo / Multiple Sellers $1,765 Delaware Basin
10/31/2016 $1,000 East Texas
10/25/2016 Multiple Sellers $683 Appalachia
10/24/2016 $400 Eagle Ford, Austin Chalk
10/20/2016 $360 Appalachia
10/18/2016 $1,600 Midland Basin
10/18/2016 $785 Bakken
10/14/2016 $742 California
10/13/2016 $2,400 Delaware Basin
10/3/2016 $235 Permian Basin
9/26/2016 $2,700 Appalachia, Barnett
9/12/2016 $2,000 Gulf of Mexico
9/9/2016 $420 Mid-Continent
Jefferies Advisory Role9
0%
10%
20%
30%
40%
50%
60%
Jan-16 Feb-16 Mar-16 Apr-16 May-16 Jun-16 Jul-16 Aug-16 Sep-16 Oct-16 Nov-16 Dec-16
A Index BBB Index BB Index B Index CCC Index Permian Comps
E&P Debt Performance (1)
-
0.20
0.40
0.60
0.80
1.00
1.20
1.40
1.60
Jan-16 Feb-16 Mar-16 Apr-16 May-16 Jun-16 Jul-16 Aug-16 Sep-16 Oct-16 Nov-16 Dec-16 Jan-17
Small Cap Large Cap Majors MLPs SPDR XOP S&P 500
E&P Equity Index Performance
Capital Markets Environment Continues to Improve
(2) (3) (4) (5) (6) (7)
1.9%
4.8%
3.1%
11.5%5.9%
Peak Yield %
4.6%
Source: CapIQ as of 1/03/17.(1) Yield indices illustrate weighted average yield based on size of issuance.(2) A Index includes issues from COP and OXY.(3) BBB Index includes issues from APA, APC, DVN, ECA, EOG, EQT, HES, MRO, MUR, NBL, PXD and XEC. (4) BB Index includes issues from the following : AR, CXO, CLR, EGN, FANG, NFX, PDCE, QEP and SWN.(5) B Index includes issues from the following: CRZO, CrownRock, GPOR, LPI, MRD, MTDR, OAS, RICE, RSPP, SM, SN, WLL and WPX.
(6) CCC Index includes issues from the following : ALTA, AREX, BBG, CRC, CWEI, DNR, EVEP, LGCY, LNR and NOG.(7) Permian comps include AREX, CPE, CXO, FANG, EGN, LPI, MTDR, PE, PXD, REI, CWEI and RSPP.
54.3%
23.7%
12.5%
8.1%4.0%
11.2%
10
Public Equity Issuances ($MM)
Public Debt Issuances ($MM)
$7,582
$1,150
$500
$2,450
$-$350
$6,100
$3,050
$4,845
$3,400 $2,789
$200 $- $-
$1,530 $850
$1,250
$1,520
$7,425
$-$711
$1,656
$142
$3,488
$-
$1,000
$2,000
$3,000
$4,000
$5,000
$6,000
$7,000
$8,000
Tran
sact
ion
Valu
e ($
MM
)
$5,544
$996
$3,044
$5,511
$792
$1,529 $1,415
$303 $176
$1,286
$466 $116 $256
$2,119
$6,900
$972
$1,463 $1,533
$2,824 $2,319
$2,084 $2,460
$72
$3,403
$-
$1,000
$2,000
$3,000
$4,000
$5,000
$6,000
$7,000
$8,000
Tran
sact
ion
Valu
e ($
MM
)
Note: Analysis excludes private company issuances, private placements, and exchange offers.
# of Issues 0 1 9 7 10 5 5 1 0 0 2 1 3 4 8 0 2 5 1 7 12 2 1 5
1H 2015: ~$17.7 B (32 deals)
2H 2015: ~$5.4 B (9 deals)
2016 YTD: ~$27.8 B (50 deals)
# of Issues 3 6 12 3 6 4 1 1 3 2 1 1 4 8 4 5 6 5 6 4 5 4 1 8
1H 2015: ~$13.3 B (34 deals)
2H 2015: ~$2.6 B (9 deals)
2016 YTD: ~$31.7 B (60 deals)
Upstream Public Market New Issue Activity Equity and Debt Capital Markets Still Willing to Participate for High Quality Assets and Operators
11
U.S. E&P Deal Volume Since 2013 ($B)
Recent A&D Trends – Extremely Correlated to Oil Price Fall / Volatility
Source: Jefferies internal transactions database.
12
$8 $9
$13
$21
$17
$27
$33
$21
$2
$9
$12 $11
$6
$18 $20
$25
$0
$10
$20
$30
$40
Q12013
Q22013
Q32013
Q42013
Q12014
Q22014
Q32014
Q42014
Q12015
Q22015
Q32015
Q42015
Q12016
Q22016
Q32016
Q42016
$ M
illio
ns
Asset Corporate JV
Total E&P A&D Transactions by Buyer Type
First Half of 2016 Driven by Private Capital,Second Half Driven by Public Companies
Source: Jefferies internal transactions database.
0%
10%
20%
30%
40%
50%
60%
70%
2011 2012 2013 2014 2015 2016 YTD
Public Private Private Equity MLP Majors/Int'ls Other
13
2016 U.S. Upstream M&A Transactions by Play
2016 U.S. Upstream M&A Transaction Count
2016 U.S. Upstream M&A Transaction Volume ($B)
Permian Leads the Way
8 22 25 18
49
85
61
81
Q1 2016 Q2 2016 Q3 2016 Q4 2016
Permian Midcontinent Ark-La-Tex Rockies Eastern Other
$1.3 $3.8
$11.2 $11.8 $5.7
$17.8 $20.3
$24.9
Q1 2016 Q2 2016 Q3 2016 Q4 2016
Permian Midcontinent Ark-La-Tex Rockies Eastern Other
Source: PLS and public company filings.Note: “Other” category includes Alaska, Gulf Coast, Gulf of Mexico, Multi-Region and West Coast transactions.
14
Three Themes – Single Play Bolt-on, New Core Area Diversification, orNew Private Capital Backed
Source: PLS and public company filings.Energy deal is either 1) Single play bolt-on, 2) New core area to diversify, 3) New private capital backed company.
Rank Date Buyer Seller Size ($MM) Play Consideration
1 May-16 Range Resources Memorial Resource Development $ 4,400 Ark-La-Tex Stock
2 Sep-16 Rice Energy Vantage Energy 2,700 Marcellus Cash and Stock
3 Sep-16 EOG Resources Yates Petroleum 2,451 Delaware Cash and Stock
4 Dec-16 Diamondback Energy Brigham Resources 2,430 Delaware Cash and Stock
5 Oct-16 RSP Permian Silver Hill Energy 2,400 Delaware Cash and Stock
6 Sep-16 Anadarko Petroleum Freeport-McMoRan 2,000 Gulf of Mexico Cash
7 Dec-16 Gulfport Energy Vitruvian Exploration II 1,850 SCOOP/STACK Cash and Stock
8 Oct-16 Occidental PetroleumJ Cleo Thompson, Permian Resources, Browning Oil
1,765 Delaware Cash
9 Jul-16 Riverstone, Silver Run Centennial Resource Development 1,735 Delaware Cash
10 Aug-16 Concho Resources Reliance Energy, Peregrine Petroleum 1,625 Midland Cash and Stock
11 Oct-16 SM Energy QStar 1,600 Midland Cash and Stock
12 Aug-16 PDC Energy Arris Petroleum, 299 Resources 1,505 Delaware Cash and Stock
13 Dec-16 Alta Resources Anadarko Petroleum 1,240 Marcellus Cash
14 Oct-16 Castleton Commodities Anadarko Petroleum 1,000 Haynesville Cash
Total $ 28,701
15
Normalized EUR Evolution
1.4
2.0
2.7
2014 2015 Current
Improvement in EURs for Selected Plays Drives Increasing Valuations
Haynesville Shale (Bcf / 1,000’) (3)
121 132
158
2014 2015 Current
Delaware Basin (MBoe / 1,000’) (4)
103
151 159
2014 2015 Current
Eagle Ford Shale (MBoe / 1,000’) (1)
62
77 82
2014 2015 Current
Williston Basin (MBoe / 1,000’) (2)
(1) Metrics include publicly available data from the following operators: CHK, CRZO, CWEI (Eastern Eagle Ford), ECA, EOG, EPE, MRO, NBL, PXD, SFY and SM. “Current” represents the most recent publicly reported data for each operator. Public disclosures represent Lower Eagle Ford completions. EURs represent type wells across all phase windows, including wet gas.
(2) Metrics include publicly available data from the following operators: CLR, HES, EOG, ERF, MRO, OAS, QEP, SM, WLL and WPX. “Current” represents the most recent publicly reported data for each operator. Public disclosures represent Middle Bakken and Three Forks completions.
(3) Metrics include publicly available data from the following operators: CHK, ECA and EPE. (4) Metrics include publicly available data from the following operators: APA, APC, CWEI, CXO, EGN, EOG, MTDR, OXY, REN, WPX, XEC. “Current” represents the most recent publicly reported data for each
operator. Public disclosures represent Bone Spring and Wolfcamp completions.16
Permian Basin Crude Production
-
2,000
4,000
6,000
8,000
10,000
12,000
14,000
16,000
18,000
20,000
2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025 2026
Per
mia
n B
asin
Oil
Pro
duct
ion
(MB
bl/d
)
Historical Production Base Case 350 Rig Case 400 Rig Case 1,000 Rig Case
Forecasted Permian Basin Production
(1) Represents processed EUR.(2) As of 11/23/2016 per Baker Hughes International.
17
Permian Will Ultimately be Largest Producing Area in the World
(1) Assumes development of 8 wells / section for the Wolfcamp A-X/Y Sand in southern Eddy County, NM and northern Loving County, TX.
Total Core Surface Acreage ~7,700,000 acres
Total Core “Effective” Acreage ~20,100,000 acres
Productive Benches 5 (Delaware)4 (Midland)
Assumed Spacing 8-15 wells / section
Number of Wells to Develop ~316,000 wells
Average EUR / Well 1,137 MBoe(730 MBo)
Total Recoverable Resource ~325 BBoe(~212 BBo)
Peak Oil Production (400 Rig Ramp) ~11,000 MBo/d
Oil Reserves Half Life (400 Rig Ramp) ~32 Years
Total Capital Needed ~$1.9 Trillion
18
PV-15 @ NYMEX ($ / Undeveloped Net Acre)(1)
What’s a Permian Acre Worth?
Note: Represents ~520 gross locations in the Middle Spraberry, Lower Spraberry, Wolfcamp A and Wolfcamp B across 10,000 net acres in Midland Co. (1) Assumes NYMEX strip pricing as of November 28, 2016.
$177,452
$150,595
$129,458
$113,073
$100,031
$-
$50,000
$100,000
$150,000
$200,000
10 15 20 25 30
Project Development Time Frame (Years)
Illustrative Example: 10,000 Acre Midland Basin Development Program
19
Top 10 Permian OperatorsOperator Net Acres Current Production Active Permian Rigs
~2,000,000 ~174 MBoe/d 10 rigs
~1,700,000 ~159 MBoe/d 5 rigs
~1,500,000 ~115 MBoe/d 10 rigs
~1,400,000 ~144 MBoe/d 8 rigs
~710,000 ~179 MBoe/d 17 rigs
~705,000 ~153 MBoe/d 18 rigs
~560,000 NA 8 rigs
~300,000 ~67 MBoe/d 5 rigs
~235,000 ~50 MBoe/d 10 rigs
~220,000 ~86 MBoe/d 5 rigs
Top 10 Total ~9,330,000 ~1,127 MBoe/d (35% of total)
96 rigs(36% of total)
Permian Basin Total ~3,250 MBoe/d (1) 267 rigs
Note: Acreage includes non-core Delaware and Midland Basin, Central Basin Platform and New Mexico Shelf.Source: Company filings and investor presentations, EIA and Baker Hughes.(1) Represents 2-stream production.
20
Declining Number of FIDs May Lead to Oil Supply Decrease
Source: Wood Mackenzie; global upstream data
0
2
4
6
8
10
12
14
16
18
Q1Q2Q3Q4Q1Q2Q3Q4Q1Q2Q3Q4Q1Q2Q3Q4Q1Q2Q3Q4Q1Q2Q3Q4Q1Q2Q3Q4Q1Q2Q3Q4Q1Q2Q3Q4Q1Q2Q3
2007 2008 2009 2010 2011 2012 2013 2014 2015 2016
Num
ber
of P
roje
cts
Onshore Shallow Deep Ultra Deep
21
60
65
70
75
80
85
90
95
100
105
2016 2017 2018 2019 2020 2021
Estimated Global Oil Demand (0.7% Annual Growth) Estimated Global Production Capacity (2.5% Annual Decline)
Estimated Global Production Capacity (5.0% Annual Decline) Estimated Global Production Capacity (7.5% Annual Decline)
Projected Oil Supply / Demand Dynamics (MMBbls/d)
Oil Supply Needed to Meet Future Demand
Source: ExxonMobil - The Outlook for Energy: A View to 2040 and IEA Oil Market Report, November 2016.
12.8MMBbls/d
23.5MMBbls/d
33.1MMBbls/d
Projected UndersupplyQ4’16 Estimated Global
Production Capacity: 99.5 MMBbls/d
Q4’16 Estimated Global Oil Demand:
97.1 MMBbls/d
22
Lots of attention on OPEC hanging together to help oil price. Can the various countries meet promises to cut production?
Longer term fundamentals for higher oil price look attractive
This phase of Permian deal flow is on the back half but there will continue to be a great deal of interest in all types of Permian
Longer term outlook for Permian deal flow could include corporate deals
Private capital markets will remain robust and will be increasingly flexible
Public capital markets will be attractive if oil price holds
Play economics will continue to improve with advancing technology
Capital costs may have upward pressure because service companies need to be able to make some money
Asset deal flow will be good in multiple plays, corporate deals could emerge
Closing Comments – Near Term Outlook
23