prompt oil price ($/bbl) $41.07 $0.32 0.8% let’s …...2020/07/27 · ark-la-tex 4% gulf of...
TRANSCRIPT
1
July 27, 2020
$2.2
$8.0
$9.9 $10.7
$4.9
$15.8
$21.2 $21.9 $24.1
$17.0
$9.1 $9.2
$20.8
$8.2
$31.6
$19.5
$1.7
$17.0
$9.0
$0.9 $2.5
$13.1
--
50
100
150
200
250
300
350
400
450
500
--
$5
$10
$15
$20
$25
$30
$35
$40
1Q15 2Q15 3Q15 4Q15 1Q16 2Q16 3Q16 4Q16 1Q17 2Q17 3Q17 4Q17 1Q18 2Q18 3Q18 4Q18 1Q19 2Q19 3Q19 4Q19 1Q20 2Q20 3Q20
61% 83% 74% 79% 39% 52% 62% 71% 93% 24% 68% 82% 91% 64% 46% 93% 51% 95% 74% 78% 67% 45% 41%
Nu
mb
er
of
Tra
nsacti
on
s
Tra
nsacti
on
Valu
e (
$b
n)
Asset Corporate Number of Transactions
% Oil% Oil% Oil
$64.3
IndicatorCurrent
Value
Week's
Change
%
Change Direction
Prompt Oil Price ($/bbl) $41.07 $0.32 0.8%
Prompt Gas Price ($/mmbtu) $1.79 $0.06 3.6%
Wkly Trans. Value ($mm) $13,000 $12,908 nmf
Wkly Trans. Count 3 -- --
US Rig Count 251 (2) (0.8%)
US Oil Prod'n (mmbbl/d) 11.1 0.1 0.9%
US Gas Prod'n (bcf/d)(1) 112.3 -- --
US Oil Storage (mmbbl) 536.6 4.9 0.9%
US Gas Storage (tcf) 3.2 0.0 1.2%
Chevron announced it acquired Noble Energy for $13 billion
in stock and assumed debt (see page 4 for more detail)
BMO Capital Markets has launched a new digital resource to
help clients navigate the impact of the pandemic, with new
insights on the reopening published every two weeks – read
more here
Debt
Markets
9 issuers priced 9 tranches for approximately $4.9 billion in proceeds last week
U.S. high yield funds reported an inflow of $3.9 billion
ETFs reported an inflow of $2.4 billion, while mutual funds reported an inflow of $1.5 billion
High yield index yield was 5.61%; high yield energy index yield was 9.50%
Source: BMO Transaction Database, Baker Hughes, BMO Commodity Products Group, Bloomberg, EIA, PLS
Note: Current quarter’s data is through the week covered by this issue.
1. EIA U.S. natural gas gross withdrawals and production reported monthly as of Apr 2020.
2. S&P E&P = S&P Oil & Gas E&P Select Industry, SPX = S&P 500 Index.
Key Industry Indicators
Quarterly Deal Activity
S&P E&P(2) outperformed last week 5.0% vs. SPX(2) 0.3%
The U.S. equity indexes mostly finished up last week. Consumer discretionary, consumer staples,
industrials, materials, healthcare, and financials finished up. Real estate and tech finished down
Equity
Markets
Oil ended last week up. Crude futures remained mostly unchanged last week despite coronavirus cases
increasing in many countries, as announcements about a potential COVID-19 vaccine gained traction
and ongoing discussions over a European Union fund to revive economies hit by the pandemic curbed
any substantial losses. According to the EIA, U.S. crude inventories increased by 4.9 million barrels from
the previous week. At 536.6 million barrels, U.S. crude inventories are 19% above the 5-year average for
this time of year. The near-term contract closed up $0.32, or 0.8%, at $41.07
Gas ended last week up. Natural gas futures increased slightly last week as hotter than normal weather
swept across most of the country. This despite natural gas storage’s continued build with 33 Bcf injected.
The near-term contract closed up $0.06, or 3.6%, at $1.79
Commodities
Week in Review
Let’s follow these guidelines when sorting articles:
• First priority: Domestic A&D, ranked by size
• Next: Domestic M&A
• Then: US companies doing international deals (like
Noble’s Tamar)
• Then: Others (Cabot’s Lackawanna)
• Then: Prices, rig count, completions, etc.
To paste the arrows with colors,
• FactSet
• Settings
• Presentation Linking and Formatting
• Import
• Colors
• Change Color Font Covering the Week of July 17 to July 23, 2020
This is the final issue for 2018. The Market Monitor will
return on Monday, January 7th. Happy Holidays from the
BMO Capital Markets team!
BMO is marketing PayRock Energy’s divestiture of South
Texas Eagle Ford assets (see page [x])
The October issue of BMO Calgary’s A&D (Canadian) Market
Monitor went live last week – read more here
One E&P deal priced last week
WPX Energy (b1/BB-) priced $600 million of x% Senior
Notes due 2027
One E&P issuer priced last week
Noble Energy priced $500 million of 3.25% senior notes
due 2029 and $500 million of 4.20% senior notes due
2049. BMO Capital Markets acted as a Joint
Bookrunner on this transaction
All references to last week in the comments below are through Thursday
Better international/demand data and promise for strict quota adherence by Russia
Demand signals continue to trend positively, with China’s total oil demand is nearly back to the pre-COVID levels of 13.4MM. U.S. real-time
mobility data indicated that driving activity has also recovered much of the April losses. Markets were also affected by greater than expected
Lower 48 shut-ins announced during earnings season. Jet-fuel market remains extremely weak thought travel started to tick higher off historic
lows.
Fighting in Libya intensified
The EIA announced a smaller-than-expected natural gas storage build. EQT confirmed that they had shut-in a large percentage of production
due to pricing, with management noting that sales were being deferred to take advantage of an expected significant improvement in price in the
coming months. LNG cancellations continued. Temperatures across the southern states expected to increase.
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July 27, 2020
Ann'd
Date Buyer Seller Area Asset Description Value(1)
Proved
Multiple
Prod.
Multiple Net Acres
($mm) ($/boe) ($/boe/d) ($/acre)
10-Jul-20 Presidio Petroleum Templar Energy LLC Mid-Continent 273,400 net acres in Anadarko Basin $91 $1.78 $5,056 $333
08-Jul-20 Undisclosed Buyer Harvest Oil & Gas Corp Marcellus/Utica 713,401 net acres in Appalachia $21 $1.23 $4,201 $29
26-Jun-20 MP III Echo LLC Echo Energy Partners Mid-Continent 19,989 net acres in Anadarko Basin $33 n.a. $4,198 $1,649
22-Jun-20 Talos Energy Castex Energy Gulf of Mexico Gulf of Mexico assets $65 $3.69 $10,156 n.a.
15-Jun-20 Sixth Street Partners Antero Resources Marcellus/Utica Overriding royalty interests in Appalachia $402 n.a. n.a. nmf
04-Jun-20 Undisclosed Buyer Black Stone Minerals Permian Midland Basin mineral and royalty assets $55 n.a. n.a. nmf
04-Jun-20 Pegasus Resources LLC Black Stone Minerals Permian Permian Basin mineral and royalty assets $100 n.a. n.a. nmf
11-May-20 Diversified Gas & Oil EQT Marcellus/Utica Appalachia Basin asset in PA and WV $125 $2.60 $13,889 n.a.
11-May-20 Morning Star Oil Co Southland Royalty Co Other Rockies 205,000 net acres in San Juan Basin $53 n.a. $3,635 $260
04-May-20 National Fuel Gas Shell Marcellus/Utica 450,000 net acres in Appalachia $541 $4.57 $12,983 $1,202
Blue = BMO provided transaction advisory services Green = BMO provided acquisition financing or related services
Purple = BMO provided both transaction advisory services and acquisition financing or related services
Permian21%
Rockies (ex. Bakken)
10%
Bakken3%
Appalachia8%
Mid-Con9%
Eagle Ford4%
Ark-La-Tex4%
Gulf of Mexico8%
Other33%
LTM By Region
y = 21.51e-0.059x
R² = 0.2514
--
$10
$20
$30
$40
$50
$60
-- 5.0x 10.0x 15.0x 20.0x 25.0x 30.0x
Sa
les
Pri
ce
/ P
rove
d R
es
erv
es
($
/bo
e @
15
:1)
R / P
R / P
Sales Value /
Proved Reserves
(15:1)
(ratio) ($ / boe) ($ / mcfe)
8x $13.38 $0.89
10x $11.89 $0.79
15x $8.84 $0.59
20x $6.57 $0.44
Oil45%
Gas55%
LTM By Commodity
Public Company
48%
PE / PE-Backed
12%Private13%
Other27%
LTM By Buyer Type
$16.3 $27.8
$18.2 $7.4 $2.7
$7.5
$14.9
$11.4
$63.0
$13.9
$23.8
$42.7
$29.6
$70.3
$16.5
2016 2017 2018 2019 2020
596 968 635 122 69
Asset Corporate
Deal Count
The 10 Most Recent Asset Transactions Over $20 Million
A&D Valuation Trends(3)
Source: BMO Transaction Database, Baker Hughes, BMO Commodity Products Group, Bloomberg, PLS
1. Represents total enterprise value. 2. Calculated as percentage of total LTM transaction count (number of transactions, not dollar value).
3. 68 transactions from January 2015 to 2019 with transaction value >$20mm. Adjusted for changes in price outlooks. Recalculated boe reserves are on a 15:1
(gas:oil) basis. Acreage transactions excluded by using deals with PDP of >= 40% of total proved.
4. Year-to-date data is through this week’s date for each respective year.
(2) (2) (2)
Confirm number of transactions weekly --->
Deal Activity – YTD ($bn)(4)
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July 27, 2020
7/23/2020
Appalachia 5
Ark-La-Tex 2
Bakken --
Eagle Ford 4
Mid-Con --
Other 2
Permian --
Rockies 1
14
Select Significant Deals on the Market
Disclaimer: The foregoing links are for convenience only and relate to materials that were not prepared or reviewed by BMO Capital Markets. BMO Capital Markets takes
no responsibility for and makes no representations with respect to the contents thereof. These materials may be inconsistent with the views of BMO Capital Markets.
Source of Select Significant Deals on the Market: BMO Transaction Database
Source of Headlines: Press releases
Industry Headlines
(Click headline to link to the full article)
M&A&D Headlines
Appalachia
5 Deals
Mid-Con
0 Deals
Eagle Ford
4 Deals
Permian
0 Deals
Other
2 Deals
Rockies
1 Deal
Bakken
0 Deals
Ark-La-Tex
2 Deals
BMO Deals (Status)
Siltstone Appalachia (In Market) – See page 6
Texas Regulators Ask Washington to Act Against
Saudi Oil Dumping in U.S.
The Lessons Oilfield Service Companies Are Applying
from Downturns Past to Succeed Today
World Bank: Global Gas Flaring at Its Highest Since
2009
EIA: U.S. Crude Inventories Up 4.9 MMbbl
California, New York, Other States Sue U.S. Over
Trump Clean-Water Rollback
Chevron Announces Agreement to Acquire Noble
Energy
Talos Energy Announces Full Year 2019 Operating
and Financial Guidance (includes A&D
announcement)
+ the EQT mineral/JV Deal
+ Antero ORRI deal
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Purchase Price (US$ mm)
Total Consideration $13,000
Implied Upstream Value(1) $11,514
Metrics
Net Acreage 463,000
Q1 2020 Net Production (mboe/d) 390
Proved Reserves (mmboe) 2,050
LTM EBITDAX ($mm) $2,585
Multiples
TEV / Net Acre ($/acre) $24,868
TEV / Production ($/boe/d) $29,522
TEV / Proved Reserves ($/boe) $5.62
TEV / EBITDAX 4.5x
DJ Basin
Permian
Basin Eagle Ford
West Africa
Eastern
Mediterranean
Purchase Price (US$ mm)
Total Consideration $525
Metrics
Net Undeveloped Acres(1) 224,000
2020E Net Production (boe/d)(2) 16,380
PDP Reserves (mmboe)(2) 24
2P Reserves (mmboe)(2) 101
Cash Flow ($mm) $109
Multiples
TEV / Net Undeveloped Acres ($/acre) $2,344
TEV / Adj. Net Undeveloped Acres ($/acre)(3) $540
TEV / 2020E Net Production ($/boe/d) $32,051
TEV / PDP Reserves ($/boe) $21.73
TEV / 2P Reserves ($/boe) $5.21
TEV / Cash Flow $4.8
Increases Parsley’s corporate flexibility and
operational scale with the integration of Jagged Peak’s
$90 million investment in water infrastructure
Facilitates margin expansion and enhances free cash
flow by producing G&A savings of ~$25 million in the
first year and $40-50 million of annual savings
thereafter, translating to a NPV of $250-300 million
On June 20, 2020, Chevron Corporation (NYSE: CVX)
(“Chevron”) announced that it has entered into a
definitive agreement with Noble Energy, Inc.
(NASDAQ: NBL) (“Noble”) to acquire Noble in an all-
stock transaction valued at $5 billion, or $10.38 per
share. The total enterprise value, including debt, of the
transaction is $13 billion
Based on Chevron’s closing price on July 17,
2020, Noble shareholders will receive 0.1191
shares of Chevron for each Noble share
TRANSACTION SUMMARY
Source: Company disclosure, Enverus
1. $1.486 billion attributed to Noble's ~62.6% stake in Noble Midstream Partners (NASDAQ: NBLX) based on NBLX's enterprise value as of 17-Jul-2020.
TRANSACTION OVERVIEW
Operates primarily in the U.S. onshore, Eastern
Mediterranean, and West Africa
U.S. includes DJ Basin, Permian Basin, and Eagle
Ford assets as well as certain exploration acreage
– DJ Basin covers 336,000 net acres
– Permian Basin covers 92,000 net acres
– Eagle Ford covers 35,000 net acres
Eastern Mediterranean holds 39.6% operated WI
in Leviathan, 25% operated WI in Tamar, and 2
exploration blocks in Cyprus
2.05 billion boe of 1P Reserves as of 31-Dec-2019
20% oil and condensate, 14% NGLs, 66% gas
73% PD
48% United States, 46% Israel, 6% Equatorial
Guinea
390 mboe/d of total sales volume during Q1 2020
35% oil and condensate, 18% NGLs, 47% gas
69% United States, 17% Israel, 14% Equatorial
Guinea
Holds 62.6% limited partner interest and the entire
non-economic general partner interest in Noble
Midstream Partners (NASDAQ: NBLX)
Interesting Deal of the Week:
Chevron Announces Agreement to Acquire Noble Energy for $13 Billion
ASSET MAP ACQUISITION METRICS
OBSERVATIONS
HighPeak Assets
Adjusted based on production multiple of
$2,000/mcfe/d.
TRANSACTION OBSERVATIONS
This transaction will add 18% to Chevron’s 2019YE
proved oil and gas reserves for less than $5/boe and
almost 7 billion barrels of risked resource for less than
$1.50/boe
Noble’s assets will enhance Chevron’s portfolio in the
U.S. with a new position in the DJ Basin and
complementary acreage in the Permian and
internationally in Israel and West Africa
This transaction is expected to achieve cost synergies
of $300 million before-tax, within a year of closing
Noble Acreage
5
July 27, 2020
Market Insight: Assessing the Impact on M&A Activity Levels During Crises
from 1998 through Q1 2020
Source: FactSet
Note: The CBOE Volatility Index (VIX) is used as a proxy for equity volatility; ‘low volatility’ defined as periods with VIX levels below 20 and ‘high volatility’ defined as periods
with VIX levels above 20.
1. Aggregate North American transaction volumes and values over $50mm by quarter from 1998 through Q1 2020.
2. Financial buyers as a percentage of total transactions. 3. Public sellers as a percentage of total corporate transactions; asset sales are excluded.
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DEAL VOLUME BY QUARTER(1)
--
150
300
450
600
1998 2000 2002 2004 2006 2008 2010 2012 2014 2016 2018 2020
Dot Com
Bubble
Global
Financial
Crisis
9/11
Attack COVID-19
OPEC+
M&A activity has typically
rebounded within 2 to 4
quarters post crisis
299
251
Low Volatility High Volatility
DEALS PER QUARTER(1)
AVERAGE DEAL VALUE
(US$MM)
$916 $802
Low Volatility High Volatility
Fewer deals get done…
14%
11%
Low Volatility High Volatility
…and deals that do get done
are smaller
FINANCIAL BUYERS(1)(2) PUBLIC SELLERS(1)(3)
37%
46%
Low Volatility High Volatility
Financial buyers retrench due
to constrained access to
leverage
More public companies
become targets in part due to
observable distressed
valuation benchmarks vs.
private companies
Sharp decline in aggregate M&A deal volume and value during periods of high volatility is typically
followed by robust recovery when volatility subsides
6
July 27, 2020
NYMEX Gas Futures as of 23-Jul-20 Close ($/mmbtu)
Period(1) Current Last Wk. 6 Mo. Ago 1 Yr. Ago
12 Mo. Strip $2.42 $2.41 $2.16 $2.45
2020 $2.14 $2.10 $2.12 $2.52
2021 $2.61 $2.61 $2.38 $2.56
2022 $2.47 $2.46 $2.41 $2.60
2023 $2.45 $2.42 $2.46 $2.67
2024 $2.48 $2.43 $2.50 $2.75
NYMEX Gas Futures as of 23-Jul-20 Close ($/mmbtu)Period(1)CurrentLast Wk.6 Mo. Ago1 Yr. Ago12 Mo. Strip$2.42$2.41$2.16$2.452020$2.14$2.10$2.12$2.522021$2.61$2.61$2.38$2.562022$2.47$2.46$2.41$2.602023$2.45$2.42$2.46$2.672024$2.48$2.43$2.50$2.75
25%
35%
45%
55%
65%
Jan-17 Jul-17 Jan-18 Jul-18 Jan-19 Jul-19 Jan-20 Jul-20
% o
f W
TI
NGL as % of WTI
$1
$2
$3
$4
$5
Jul-19 Jan-20 Jul-20 Jan-21 Jul-21
($/m
mb
tu)
$10
$20
$30
$40
$50
$60
$70
Jul-19 Jan-20 Jul-20 Jan-21 Jul-21
($/b
bl)
NYMEX Gas Futures as of 23-Jul-20 Close ($/mmbtu)Period(1)CurrentLast Wk.6 Mo. Ago1 Yr. Ago12 Mo. Strip$2.42$2.41$2.16$2.452020$2.14$2.10$2.12$2.522021$2.61$2.61$2.38$2.562022$2.47$2.46$2.41$2.602023$2.45$2.42$2.46$2.672024$2.48$2.43$2.50$2.75
NYMEX WTI Futures as of 23-Jul-20 Close ($/bbl)NYMEX Gas Futures as of 23-Jul-20 Close ($/mmbtu)Period(1)CurrentLast Wk.6 Mo. Ago1 Yr. Ago12 Mo. Strip$41.86$41.57$54.35$56.062020$41.29$41.08$54.67$55.472021$42.37$42.20$51.79$53.402022$43.54$43.26$50.35$52.542023$44.63$44.32$50.07$52.552024$45.61$45.38$50.35$53.00
NYMEX WTI Futures as of 23-Jul-20 Close ($/bbl) NYMEX Gas Futures as of 23-Jul-20 Close ($/mmbtu)
Period(1) Current Last Wk. 6 Mo. Ago 1 Yr. Ago
12 Mo. Strip $41.86 $41.57 $54.35 $56.06
2020 $41.29 $41.08 $54.67 $55.47
2021 $42.37 $42.20 $51.79 $53.40
2022 $43.54 $43.26 $50.35 $52.54
2023 $44.63 $44.32 $50.07 $52.55
2024 $45.61 $45.38 $50.35 $53.00
NYMEX WTI Futures as of 23-Jul-20 Close ($/bbl)NYMEX Gas Futures as of 23-Jul-20 Close ($/mmbtu)Period(1)CurrentLast Wk.6 Mo. Ago1 Yr. Ago12 Mo. Strip$41.86$41.57$54.35$56.062020$41.29$41.08$54.67$55.472021$42.37$42.20$51.79$53.402022$43.54$43.26$50.35$52.542023$44.63$44.32$50.07$52.552024$45.61$45.38$50.35$53.00
Historical Prices as of 23-Jul-20 Close ($/gal)NGLsCurrentLast Wk.6 Mo. Ago1 Yr. AgoEthane$0.22$0.22$0.14$0.16Propane$0.52$0.48$0.40$0.50Butane$0.53$0.49$0.80$0.47Iso-butane$0.59$0.58$0.91$0.67Pentane+$0.70$0.64$1.17$1.04 Historical Prices as of 23-Jul-20 Close ($/gal)NGLsCurrentLast Wk.6 Mo. Ago1 Yr. AgoEthane$0.22$0.22$0.14$0.16Propane$0.52$0.48$0.40$0.50Butane$0.53$0.49$0.80$0.47Iso-butane$0.59$0.58$0.91$0.67Pentane+$0.70$0.64$1.17$1.04
Historical Prices as of 23-Jul-20 Close ($/gal)
NGLs Current Last Wk. 6 Mo. Ago 1 Yr. Ago
Ethane $0.22 $0.22 $0.14 $0.16
Propane $0.52 $0.48 $0.40 $0.50
Butane $0.53 $0.49 $0.80 $0.47
Iso-butane $0.59 $0.58 $0.91 $0.67
Pentane+ $0.70 $0.64 $1.17 $1.04
NGL PRICING(2)
HENRY HUB NATURAL GAS (HISTORICAL / FORECAST)
Commodity Prices
Source: BMO Commodity Products Group, Bloomberg, FactSet
1. Future prices are calendar year average unless stated otherwise.
2. Assumes typical Gulf Coast barrel composition.
WTI OIL (HISTORICAL / FORECAST)
Links:
http://www.nasdaq.com/markets/crude-oil.aspx
http://www.bloomberg.com/quote/CL1:COM
http://www.nasdaq.com/markets/natural-gas.aspx
http://www.bloomberg.com/quote/NG1:COM
Link to Detailed
Futures Data
Link to Detailed
Historical Graph
Link to Detailed
Futures Data
Link to Detailed
Historical Graph
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July 27, 2020
AECO
Northern
California
Sumas
Southern
California
El Paso - SJ
Waha
HSC
Henry Hub
Panhandle
CIG Chicago
Dominion
Transco
$1.26
($0.53)
Clearbrook
Midland
Cushing
St. James
(LLS)
East Coast
U.S. (Brent)
Midland Sweet-
Sour Spread
EMS
NATURAL GAS PRICING & DIFFERENTIALS TO HENRY HUB ($ / MMBTU) – AS OF 23-JUL-20
Commodity Prices (cont’d)
OIL PRICING & DIFFERENTIALS TO CUSHING WTI ($ / BBL) – AS OF 23-JUL-20
Legend
Price
Diff.
$1.64
($0.15)
Legend
Price
Diff.
$1.57
($0.22)
$1.61
($0.18)
$42.20
$1.13
$1.61
($0.18)
$1.70
($0.09)
$1.91
$0.12
($0.23)
$41.07
$1.73
($0.06)
$41.20
$0.13
$43.31
$2.24
$1.47
($0.32)
$1.78
($0.01)
$37.82
($3.25)
Source: BMO Commodity Products Group, Bloomberg
Note: Prices and differentials are for prompt month futures except for Clearbrook which is based on spot prices.
$1.79
$1.46
($0.33)
$40.22
($0.85)
MAPS IN
MASTER VIEW
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$0.72
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July 27, 2020
Item Value Wkly Change Last Week Item Value Wkly Change Last Week
Rig Count 126 2 124 Oil Differential $0.15 ($0.05) $0.20
Permitting Activity 64 (19) 83 Gas Differential ($0.31) ($0.03) ($0.28)
0%
10%
20%
30%
40%
50%
60%
--
100
200
300
400
500
Jan-15 Jan-16 Jan-17 Jan-18 Jan-19 Jan-20
H V+D % of Total Rigs
-$4.80
-$3.20
-$1.60
$0.00
$1.60
2015 2016 2017 2018 2019 2020
-$18.00
-$12.00
-$6.00
$0.00
$6.00
$ /
mm
btu
$ /
bb
l
Midland Waha
4,000
8,000
12,000
16,000
20,000
1,000
2,000
3,000
4,000
5,000
Jan-15 Oct-15 Jul-16 Apr-17 Jan-18 Oct-18 Jul-19
mm
cf/
d
mb
bl/
d
Oil Gas4,802
16,919
784 753596
851744
803967
843706
544
296
494
306
Jul-19 Sep-19 Nov-19 Jan-20 Mar-20 May-20 Jul-20
H V+D
Ann'd
Date Buyer Seller Asset Description Value(1)
Proved
Multiple
Prod.
Multiple Net Acres
($mm) ($/boe) ($/boe/d) ($/acre)(2)
04-Jun-20 Undisclosed Buyer Black Stone Minerals Midland Basin mineral and royalty assets $55 n.a. n.a. nmf
04-Jun-20 Pegasus Resources LLC Black Stone Minerals Multi-Permian mineral and royalty assets $100 n.a. n.a. nmf
14-Apr-20 Undisclosed Buyer Ring Energy 19,998 net acres in Delaware Basin $32 $3.15 $34,615 $1,575
31-Mar-20 Viper Energy Partners Undisclosed Sellers 410 net royalty acres in Permian Basin $63 n.a. n.a. nmf
14-Feb-20 Undisclosed Buyer Lilis Energy Inc 1,185 net acres in Delaware Basin $25 n.a. n.a. $21,013
Mean $55 $3.15 $34,615 $11,294
Median $55 $3.15 $34,615 $11,294
Blue = BMO provided transaction advisory services Green = BMO provided acquisition financing or related services
Purple = BMO provided both transaction advisory services and acquisition financing or related services
--
$20,000
$40,000
$60,000
$80,000
1Q
15
2Q
15
3Q
15
4Q
15
1Q
16
2Q
16
3Q
16
4Q
16
1Q
17
2Q
17
3Q
17
4Q
17
1Q
18
2Q
18
3Q
18
4Q
18
1Q
19
2Q
19
3Q
19
4Q
19
1Q
20
2Q
20
1 2 8 8 6 6 121315 7 2 2 7 2 5 4 1 2 0 3 0 2
$ /
acre
# Deals
$23,957
--
$50,000
$100,000
$150,000
$200,000
1Q
15
2Q
15
3Q
15
4Q
15
1Q
16
2Q
16
3Q
16
4Q
16
1Q
17
2Q
17
3Q
17
4Q
17
1Q
18
2Q
18
3Q
18
4Q
18
1Q
19
2Q
19
3Q
19
4Q
19
1Q
20
2Q
20
1 2 6 9 5 7 11 9 9 6 1 0 7 2 5 4 1 2 4 3 0 1
$ /
bo
e/d
# Deals
$86,402
TRANSACTION ACTIVITY (EXCLUDES CORPORATE DEALS)
TRANSACTION PRODUCTION MULTIPLES(3) TRANSACTION ADJUSTED NET ACRE MULTIPLES(3,4)
PERMITTING ACTIVITY BY MONTH
DIFFERENTIALS
Permian Snapshot
RIG COUNT
Source: BMO Transaction Database, Baker Hughes, BMO Commodity Products Group, Bloomberg, Drilling Info, PLS
Note: Current quarter’s data is through the week covered by this issue.
1. Represents total enterprise value. Excludes transactions with deal value <$20 million. 2. $/acre multiple not adjusted for value associated with production.
3. Red line denotes average since 01-Jan-18. Calculated as the weighted average of each quarter’s transactions.
4. Production valued at $45,000/boepd in 2014, $30,000/boepd in 2015, $35,000/boepd in 2016 & 2017, $40,000/boepd in 2018 & 2019, and $30,000/boepd in 2020.
GROSS PRODUCTION (THROUGH 31-MAR-20)
[TBU]
[TBU]
[TBU] [TBU]
[TBU] [TBU]
[TBU]
[TBU]
[TBU]
[TBU]
[TBU]
[TBU]
9
July 27, 2020
0%
5%
10%
15%
20%
--
100
200
300
Jan-15 Jan-16 Jan-17 Jan-18 Jan-19 Jan-20
H V+D % of Total Rigs
Item Value Wkly Change Last Week Item Value Wkly Change Last Week
Rig Count 13 -- 13 Oil Differential $0.70 ($0.30) $1.00
Permitting Activity 5 4 1 Gas Differential ($0.01) -- ($0.01)
-$0.30
-$0.20
-$0.10
$0.00
$0.10
$0.20
$0.30
$0.40
$0.50
2015 2016 2017 2018 2019 2020
-$6.00
-$4.00
-$2.00
$0.00
$2.00
$4.00
$6.00
$8.00
$10.00
$ /
mm
btu
$ /
bb
l
MEH HSC
6,000
6,500
7,000
7,500
8,000
1,000
1,200
1,400
1,600
1,800
Jan-15 Oct-15 Jul-16 Apr-17 Jan-18 Oct-18 Jul-19
mm
cf/
d
mb
bl/
d
Oil Gas
1,397
7,371
173201 192
221 204 204
302
170180
7843 28 15
Jul-19 Sep-19 Nov-19 Jan-20 Mar-20 May-20 Jul-20
H V+D
Ann'd
Date Buyer Seller Asset Description Value(1)
Proved
Multiple
Prod.
Multiple Net Acres
($mm) ($/boe) ($/boe/d) ($/acre)(2)
21-Feb-20 Magnolia Oil & Gas Corp Undisclosed Seller Non-op Eagle Ford assets $71 n.a. $39,176 n.a.
12-Nov-19 Kimbell Royalty Partners Buckhorn Resources 400 net royalty acres in Eagle Ford $32 n.a. $117,752 nmf
07-Nov-19 Repsol Equinor 100% ownership in former Eagle Ford JV $325 n.a. $9,559 $7,476
06-Nov-19 Marathon Rocky Creek & Delago 18,000 net acres in Eagle Ford $185 n.a. $26,429 $10,278
17-Jul-19 Undisclosed Buyer Sundance Energy 6,100 net acres in Dimmit County $30 n.a. $28,069 $4,836
Mean $129 n.a. $44,197 $7,530
Median $71 n.a. $28,069 $7,476
Blue = BMO provided transaction advisory services Green = BMO provided acquisition financing or related services
Purple = BMO provided both transaction advisory services and acquisition financing or related services
--$10,000$20,000$30,000$40,000$50,000$60,000
1Q
15
2Q
15
3Q
15
4Q
15
1Q
16
2Q
16
3Q
16
4Q
16
1Q
17
2Q
17
3Q
17
4Q
17
1Q
18
2Q
18
3Q
18
4Q
18
1Q
19
2Q
19
3Q
19
4Q
19
1Q
20
0 1 2 1 2 2 0 4 2 3 1 2 4 2 1 3 0 0 0 0 0
$ /
acre
# Deals
$8,045
--
$50,000
$100,000
$150,000
1Q
15
2Q
15
3Q
15
4Q
15
1Q
16
2Q
16
3Q
16
4Q
16
1Q
17
2Q
17
3Q
17
4Q
17
1Q
18
2Q
18
3Q
18
4Q
18
1Q
19
2Q
19
3Q
19
4Q
19
1Q
20
1 1 3 1 2 2 2 4 4 3 1 2 7 2 0 3 0 0 1 3 1
$ /
bo
e/d
# Deals
$64,626
Eagle Ford Snapshot
TRANSACTION ACTIVITY (EXCLUDES CORPORATE DEALS)
PERMITTING ACTIVITY BY MONTH
DIFFERENTIALS RIG COUNT
Source: BMO Transaction Database, Baker Hughes, BMO Commodity Products Group, Bloomberg, Drilling Info, PLS
Note: Current quarter’s data is through the week covered by this issue.
1. Represents total enterprise value. Excludes transactions with deal value <$20 million. 2. $/acre multiple not adjusted for value associated with production.
3. Red line denotes average since 01-Jan-18. Calculated as the weighted average of each quarter’s transactions.
4. Production valued at $45,000/boepd in 2014, $30,000/boepd in 2015, $35,000/boepd in 2016 & 2017, $40,000/boepd in 2018 & 2019, and $30,000/boepd in 2020.
TRANSACTION PRODUCTION MULTIPLES(3) TRANSACTION ADJUSTED NET ACRE MULTIPLES(3,4)
[TBU]
[TBU]
[TBU]
GROSS PRODUCTION (THROUGH 31-MAR-20)
[TBU]
[TBU]
[TBU]
10
July 27, 2020
0%
5%
10%
15%
20%
--
20
40
60
80
Jan-15 Jan-16 Jan-17 Jan-18 Jan-19 Jan-20
H V+D % of Total Rigs
Item Value Wkly Change Last Week Item Value Wkly Change Last Week
Rig Count 32 -- 32 Oil Differential $1.90 $0.30 $1.60
Permitting Activity 2 (5) 7 Gas Differential -- -- --
-$10.00
-$5.00
$0.00
$5.00
$10.00
2015 2016 2017 2018 2019 2020
-$10.00
-$5.00
$0.00
$5.00
$10.00
$ /
mm
btu
$ /
bb
l
LLS Henry Hub
5,000
6,500
8,000
9,500
11,000
12,500
14,000
60
70
80
90
100
110
120
Jan-15 Oct-15 Jul-16 Apr-17 Jan-18 Oct-18 Jul-19
mm
cf/
d
mb
bl/
d
Oil Gas
72
12,738
108
197218
92
168
83 8289 93
43 35 4319
Jul-19 Sep-19 Nov-19 Jan-20 Mar-20 May-20 Jul-20
H V+D
Ann'd
Date Buyer Seller Asset Description Value(1)
Proved
Multiple
Prod.
Multiple Net Acres
($mm) ($/mcfe) ($/mcfe/d) ($/acre)(2)
20-Dec-19 Undisclosed Buyer Riviera Operating LLC 75,873 net acres in East Texas $34 $0.17 $1,213 $448
29-Jul-19 Osaka Gas Sabine Oil & Gas Corp 175,000 net acres in East TX $610 n.a. $2,905 $9,136
19-Dec-18 Comstock Shelby Shale LLC 6,023 net acres in Haynesville $21 n.a. n.a. $3,404
19-Nov-18 Aethon III QEP Resources Inc 49,700 net acres in Haynesville $735 $0.77 $2,475 $14,789
05-Sep-18 Viking Energy Group Multiple Sellers Texas and Louisiana assets $100 n.a. n.a. n.a.
Mean $300 $0.47 $2,198 $6,944
Median $100 $0.47 $2,475 $6,270
Blue = BMO provided transaction advisory services Green = BMO provided acquisition financing or related services
Purple = BMO provided both transaction advisory services and acquisition financing or related services
--
$5,000
$10,000
$15,000
$20,000
1Q
15
2Q
15
3Q
15
4Q
15
1Q
16
2Q
16
3Q
16
4Q
16
1Q
17
2Q
17
3Q
17
4Q
17
1Q
18
2Q
18
3Q
18
4Q
18
1Q
19
2Q
19
3Q
19
4Q
19
1Q
20
0 0 3 1 1 2 1 3 0 1 2 0 1 1 1 1 0 1 1 0 0
$ /
acre
# Deals
$3,180
--$2,000$4,000$6,000$8,000
$10,000$12,000
1Q
15
2Q
15
3Q
15
4Q
15
1Q
16
2Q
16
3Q
16
4Q
16
1Q
17
2Q
17
3Q
17
4Q
17
1Q
18
2Q
18
3Q
18
4Q
18
1Q
19
2Q
19
3Q
19
4Q
19
1Q
20
0 0 5 1 1 3 2 3 0 2 2 0 1 1 2 1 0 1 1 1 0
$ /
mcfe
/d
# Deals
$3,983
Ark-La-Tex Snapshot
TRANSACTION ACTIVITY (EXCLUDES CORPORATE DEALS)
PERMITTING ACTIVITY BY MONTH
DIFFERENTIALS RIG COUNT
Source: BMO Transaction Database, Baker Hughes, BMO Commodity Products Group, Bloomberg, Drilling Info, PLS
Note: Current quarter’s data is through the week covered by this issue.
1. Represents total enterprise value. Excludes transactions with deal value <$20 million. 2. $/acre multiple not adjusted for value associated with production.
3. Red line denotes average since 01-Jan-18. Calculated as the weighted average of each quarter’s transactions.
4. Production valued at $3,000/mcfepd in 2014, and $2,000/mcfepd in 2015, 2016, 2017, 2018, 2019, and 2020.
TRANSACTION PRODUCTION MULTIPLES(3) TRANSACTION ADJUSTED NET ACRE MULTIPLES(3,4)
GROSS PRODUCTION (THROUGH 31-MAR-20)
[TBU]
[TBU]
[TBU]
[TBU]
[TBU]
[TBU]
[TBU]
[TBU]
[TBU]
[TBU]
[TBU]
[TBU]
[TBU]
[TBU]
11
July 27, 2020
0%
5%
10%
15%
20%
--
50
100
150
Jan-15 Jan-16 Jan-17 Jan-18 Jan-19 Jan-20
H V+D % of Total Rigs
Item Value Wkly Change Last Week Item Value Wkly Change Last Week
Rig Count 31 (2) 33 Oil Differential $2.29 ($0.33) $2.62
Permitting Activity 11 (44) 55 Gas Differential ($0.58) ($0.13) ($0.44)
-$3.00
-$2.00
-$1.00
$0.00
$1.00
$2.00
$3.00
2015 2016 2017 2018 2019 2020
-$15.00
-$10.00
-$5.00
$0.00
$5.00
$10.00
$15.00
$ /
mm
btu
$ /
bb
l
Brent Dominion
15,000
20,000
25,000
30,000
35,000
80
100
120
140
160
Jan-15 Oct-15 Jul-16 Apr-17 Jan-18 Oct-18 Jul-19
mm
cf/
d
mb
bl/
d
Oil Gas
155
33,549347302 295
258232
188157
226253
186
92131
108
Jul-19 Sep-19 Nov-19 Jan-20 Mar-20 May-20 Jul-20
H V+D
Ann'd
Date Buyer Seller Asset Description Value(1)
Proved
Multiple
Prod.
Multiple Net Acres
($mm) ($/mcfe) ($/mcfe/d) ($/acre)(2)
08-Jul-20 Undisclosed Buyer Harvest Oil & Gas Corp 713,401 net acres in Appalachia $21 $0.21 $700 $29
15-Jun-20 Sixth Street Partners Antero Resources Overriding royalty interests in Appalachia $402 n.a. n.a. nmf
11-May-20 Diversified Gas & Oil EQT Appalachia Basin asset in PA and WV $125 $0.43 $2,315 n.a.
04-May-20 National Fuel Gas Shell 450,000 net acres in Appalachia $541 $0.76 $2,164 $1,202
08-Apr-20 Diversified Gas & Oil Carbon Energy Corp (USA) 1,553,754 net acres in Appalachia $110 $0.25 $1,852 $71
Mean $240 $0.41 $1,758 $434
Median $125 $0.34 $2,008 $71
Blue = BMO provided transaction advisory services Green = BMO provided acquisition financing or related services
Purple = BMO provided both transaction advisory services and acquisition financing or related services
--$2,000$4,000$6,000$8,000
$10,000$12,000
1Q
15
2Q
15
3Q
15
4Q
15
1Q
16
2Q
16
3Q
16
4Q
16
1Q
17
2Q
17
3Q
17
4Q
17
1Q
18
2Q
18
3Q
18
4Q
18
1Q
19
2Q
19
3Q
19
4Q
19
1Q
20
2Q
20
3Q
20
0 1 0 0 1 2 2 4 2 4 1 3 1 3 2 0 0 0 0 0 0 1 0
$ /
acre
# Deals
$497
--$5,000
$10,000$15,000$20,000$25,000$30,000
1Q
15
2Q
15
3Q
15
4Q
15
1Q
16
2Q
16
3Q
16
4Q
16
1Q
17
2Q
17
3Q
17
4Q
17
1Q
18
2Q
18
3Q
18
4Q
18
1Q
19
2Q
19
3Q
19
4Q
19
1Q
20
2Q
20
3Q
20
0 1 0 0 1 2 2 3 2 5 1 4 3 4 3 1 1 0 2 1 1 3 1
$ /
mcfe
/d
# Deals
$4,521
Appalachia Snapshot
TRANSACTION ACTIVITY (EXCLUDES CORPORATE DEALS)
PERMITTING ACTIVITY BY MONTH
DIFFERENTIALS RIG COUNT
Source: BMO Transaction Database, Baker Hughes, BMO Commodity Products Group, Bloomberg, Drilling Info, PLS
Note: Current quarter’s data is through the week covered by this issue.
1. Represents total enterprise value. Excludes transactions with deal value <$20 million. 2. $/acre multiple not adjusted for value associated with production.
3. Red line denotes average since 01-Jan-18. Calculated as the weighted average of each quarter’s transactions.
4. Production valued at $3,000/mcfepd in 2014, and $2,000/mcfepd in 2015, 2016, 2017, 2018, 2019, and 2020.
TRANSACTION PRODUCTION MULTIPLES(3) TRANSACTION ADJUSTED NET ACRE MULTIPLES(3,4)
[TBU]
[TBU]
[TBU]
[TBU]
[TBU]
[TBU]
[TBU]
[TBU]
[TBU]
GROSS PRODUCTION (THROUGH 31-DEC-19)
[TBU]
[TBU]
[TBU]
12
July 27, 2020
0%
5%
10%
15%
20%
--
50
100
150
200
Jan-15 Jan-16 Jan-17 Jan-18 Jan-19 Jan-20
H V+D % of Total Rigs
Item Value Wkly Change Last Week Item Value Wkly Change Last Week
Rig Count 10 -- 10 Oil Differential ($0.85) ($0.10) ($0.75)
Permitting Activity 14 3 11 Gas Differential ($0.18) -- ($0.18)
-$1.00
-$0.50
$0.00
$0.50
2015 2016 2017 2018 2019 2020
-$20.00
-$10.00
$0.00
$10.00
$ /
mm
btu
$ /
bb
l
Clearbrook CIG
1,500
1,800
2,100
2,400
2,700
3,000
3,300
3,600
900
1,000
1,100
1,200
1,300
1,400
1,500
1,600
Jan-15 Oct-15 Jul-16 Apr-17 Jan-18 Oct-18 Jul-19
mm
cf/
d
mb
bl/
d
Oil Gas 1,409
3,151
154138
110
157
8380
7867 76 67 61
83
57
Jul-19 Sep-19 Nov-19 Jan-20 Mar-20 May-20 Jul-20
H V+D
Ann'd
Date Buyer Seller Asset Description Value(1)
Proved
Multiple
Prod.
Multiple Net Acres
($mm) ($/boe) ($/boe/d) ($/acre)(2)
22-Apr-19 Northern Oil and Gas Flywheel Energy LLC 18,000 net acres in Williston Basin $310 n.a. $47,014 $17,238
31-Jul-18 Northern Oil and Gas W Energy Partners 10,600 net acres in Williston Basin $288 n.a. $42,708 $27,196
18-Jul-18 Northern Oil and Gas Pivotal Petroleum Partners LP Producing assets in Williston Basin $152 n.a. $37,032 n.a.
12-Jul-18 PetroShale Inc Slawson Exploration Co 1,981 net acres in Williston Basin $55 $6.04 $100,000 $27,764
06-Jul-18 Energy Resources 12 LP Bruin E&P Partners LLC 2.8% non-operated WI in Bakken assets $83 n.a. n.a. n.a.
Mean $178 $6.04 $56,688 $24,066
Median $152 $6.04 $44,861 $27,196
Blue = BMO provided transaction advisory services Green = BMO provided acquisition financing or related services
Purple = BMO provided both transaction advisory services and acquisition financing or related services
--
$20,000
$40,000
$60,000
$80,000
1Q
15
2Q
15
3Q
15
4Q
15
1Q
16
2Q
16
3Q
16
4Q
16
1Q
17
2Q
17
3Q
17
4Q
17
1Q
18
2Q
18
3Q
18
4Q
18
1Q
19
2Q
19
3Q
19
4Q
19
1Q
20
0 1 1 4 0 2 3 3 0 1 3 3 0 6 3 0 0 1 0 0 0
$ /
bo
e/d
# Deals
$45,752
--
$5,000
$10,000
$15,000
$20,000
$25,000
1Q
15
2Q
15
3Q
15
4Q
15
1Q
16
2Q
16
3Q
16
4Q
16
1Q
17
2Q
17
3Q
17
4Q
17
1Q
18
2Q
18
3Q
18
4Q
18
1Q
19
2Q
19
3Q
19
4Q
19
1Q
20
0 0 1 2 0 0 2 3 1 0 3 2 0 5 2 0 0 1 0 0 0
$ /
acre
# Deals
$1,751
Bakken Snapshot
TRANSACTION ACTIVITY (EXCLUDES CORPORATE DEALS)
PERMITTING ACTIVITY BY MONTH
DIFFERENTIALS RIG COUNT
Source: BMO Transaction Database, Baker Hughes, BMO Commodity Products Group, Bloomberg, Drilling Info, PLS
Note: Current quarter’s data is through the week covered by this issue.
1. Represents total enterprise value. Excludes transactions with deal value <$20 million. 2. $/acre multiple not adjusted for value associated with production.
3. Red line denotes average since 01-Jan-18. Calculated as the weighted average of each quarter’s transactions.
4. Production valued at $45,000/boepd in 2014, $30,000/boepd in 2015, $35,000/boepd in 2016 & 2017, $40,000/boepd in 2018 & 2019, and $30,000/boepd in 2020.
TRANSACTION PRODUCTION MULTIPLES(3) TRANSACTION ADJUSTED NET ACRE MULTIPLES(3,4)
[TBU]
[TBU]
[TBU]
[TBU]
[TBU]
[TBU]
[TBU]
[TBU]
GROSS PRODUCTION (THROUGH 31-MAR-20)
[TBU]
[TBU]
[TBU]
13
July 27, 2020
0%
5%
10%
15%
20%
--
50
100
150
Jan-15 Jan-16 Jan-17 Jan-18 Jan-19 Jan-20
H V+D % of Total Rigs
Item Value Wkly Change Last Week Item Value Wkly Change Last Week
Rig Count 6 -- 6 Oil Differential ($0.85) ($0.10) ($0.75)
Permitting Activity 6 (17) 23 Gas Differential ($0.18) -- ($0.18)
-$1.00
-$0.50
$0.00
$0.50
2015 2016 2017 2018 2019 2020
-$20.00
-$10.00
$0.00
$10.00
$ /
mm
btu
$ /
bb
l
Clearbrook CIG
13,000
13,500
14,000
14,500
15,000
15,500
16,000
500
600
700
800
900
1,000
1,100
Jan-15 Oct-15 Jul-16 Apr-17 Jan-18 Oct-18 Jul-19
mm
cf/
d
mb
bl/
d
Oil Gas914
13,529
286
434
327297
168213
268199
286
210 225197
59
Jul-19 Sep-19 Nov-19 Jan-20 Mar-20 May-20 Jul-20
H V+D
Ann'd
Date Buyer Seller Asset Description Value(1)
Proved
Multiple
Prod.
Multiple Net Acres
($mm) ($/boe) ($/boe/d) ($/acre)(2)
11-May-20 Morning Star Oil Co Southland Royalty Co 205,000 net acres in San Juan Basin $53 n.a. $3,635 $260
31-Jan-20 Undisclosed Buyer ConocoPhillips 98,000 net acres in DJ Basin $380 $27.14 $34,545 $3,878
09-Dec-19 YTEF Drilling Capital LLC Bayswater E&P LLC DJ Basin JV $125 n.a. n.a. n.a.
03-Sep-19 Undisclosed Buyer Crescent Point 224,000 net undeveloped acres in Uinta $525 n.a. $32,051 $2,344
14-Feb-19 Undisclosed Buyer Harvest Oil & Gas Corp San Juan Basin assets $43 $1.57 $10,835 n.a.
Mean $225 $14.36 $20,267 $2,160
Median $125 $14.36 $21,443 $2,344
Blue = BMO provided transaction advisory services Green = BMO provided acquisition financing or related services
Purple = BMO provided both transaction advisory services and acquisition financing or related services
--$20,000$40,000$60,000$80,000
$100,000$120,000
1Q
15
2Q
15
3Q
15
4Q
15
1Q
16
2Q
16
3Q
16
4Q
16
1Q
17
2Q
17
3Q
17
4Q
17
1Q
18
2Q
18
3Q
18
4Q
18
1Q
19
2Q
19
3Q
19
4Q
19
1Q
20
2Q
20
2 0 4 4 1 6 2 0 1 6 3 9 3 1 3 1 1 0 2 0 1 1
$ /
bo
e/d
# Deals
$33,614
--
$5,000
$10,000
$15,000
$20,000
1Q
15
2Q
15
3Q
15
4Q
15
1Q
16
2Q
16
3Q
16
4Q
16
1Q
17
2Q
17
3Q
17
4Q
17
1Q
18
2Q
18
3Q
18
4Q
18
1Q
19
2Q
19
3Q
19
4Q
19
1Q
20
2Q
20
0 0 3 3 0 1 1 0 1 0 1 5 2 0 2 1 0 0 0 0 1 0
$ /
acre
# Deals
$2,069
TRANSACTION ACTIVITY (EXCLUDES CORPORATE DEALS)
PERMITTING ACTIVITY BY MONTH
DIFFERENTIALS
Rockies (excl. Bakken) Snapshot
RIG COUNT
Source: BMO Transaction Database, Baker Hughes, BMO Commodity Products Group, Bloomberg, Drilling Info, PLS
Note: Current quarter’s data is through the week covered by this issue.
1. Represents total enterprise value. Excludes transactions with deal value <$20 million. 2. $/acre multiple not adjusted for value associated with production.
3. Red line denotes average since 01-Jan-18. Calculated as the weighted average of each quarter’s transactions.
4. Production valued at $45,000/boepd in 2014, $30,000/boepd in 2015, $35,000/boepd in 2016 & 2017, $40,000/boepd in 2018 & 2019, and $30,000/boepd in 2020.
TRANSACTION PRODUCTION MULTIPLES(3) TRANSACTION ADJUSTED NET ACRE MULTIPLES(3,4)
[TBU]
[TBU]
[TBU]
[TBU]
[TBU]
[TBU]
[TBU]
[TBU]
[TBU]
GROSS PRODUCTION (THROUGH 31-MAR-20)
[TBU]
[TBU]
[TBU]
14
July 27, 2020
0%
5%
10%
15%
20%
--
100
200
300
400
Jan-15 Jan-16 Jan-17 Jan-18 Jan-19 Jan-20
H V+D % of Total Rigs
Item Value Wkly Change Last Week Item Value Wkly Change Last Week
Rig Count 10 -- 10 Oil Differential -- -- --
Permitting Activity 21 (9) 30 Gas Differential ($0.19) ($0.01) ($0.18)
-$1.00
-$0.75
-$0.50
-$0.25
$0.00
$0.25
2015 2016 2017 2018 2019 2020
-$1.00
-$0.75
-$0.50
-$0.25
$0.00
$0.25
$ /
mm
btu
$ /
bb
l
Cushing Panhandle
12,000
13,200
14,400
15,600
16,800
18,000
600
650
700
750
800
850
Jan-15 Oct-15 Jul-16 Apr-17 Jan-18 Oct-18 Jul-19
mm
cf/
d
mb
bl/
d
Oil Gas702
13,138
356330 348 345 347
296 284261
203
73 82106 94
Jul-19 Sep-19 Nov-19 Jan-20 Mar-20 May-20 Jul-20
H V+D
--
$5,000
$10,000
$15,000
$20,000
1Q
15
2Q
15
3Q
15
4Q
15
1Q
16
2Q
16
3Q
16
4Q
16
1Q
17
2Q
17
3Q
17
4Q
17
1Q
18
2Q
18
3Q
18
4Q
18
1Q
19
2Q
19
3Q
19
4Q
19
1Q
20
2Q
20
3Q
20
1 3 1 2 0 3 3 2 4 1 2 1 0 0 0 1 0 0 0 0 0 0 0
$ /
acre
# Deals
$4,284
--
$50,000
$100,000
$150,000
$200,000
1Q
15
2Q
15
3Q
15
4Q
15
1Q
16
2Q
16
3Q
16
4Q
16
1Q
17
2Q
17
3Q
17
4Q
17
1Q
18
2Q
18
3Q
18
4Q
18
1Q
19
2Q
19
3Q
19
4Q
19
1Q
20
2Q
20
3Q
20
1 4 1 3 1 6 3 1 4 2 4 5 2 2 5 4 2 0 4 2 0 2 1
$ /
bo
e/d
# Deals
$17,593
Ann'd
Date Buyer Seller Asset Description Value(1)
Proved
Multiple
Prod.
Multiple Net Acres
($mm) ($/boe) ($/boe/d) ($/acre)(2)
10-Jul-20 Presidio Petroleum Templar Energy LLC 273,400 net acres in Anadarko Basin $91 $1.78 $5,056 $333
26-Jun-20 MP III Echo LLC Echo Energy Partners 19,989 net acres in Anadarko Basin $33 n.a. $4,198 $1,649
03-Apr-20 BCE-Mach III LLC Alta Mesa Resources 130,000 net acres in STACK $160 $2.22 $5,317 $1,227
10-Dec-19 Dow Devon Energy STACK Basin JV $100 n.a. n.a. n.a.
27-Sep-19 Contango White Star Petroleum LLC 314,800 net acres in Mid-Con $133 $1.57 $8,833 $421
Mean $103 $1.86 $5,851 $907
Median $100 $1.78 $5,186 $824
Blue = BMO provided transaction advisory services Green = BMO provided acquisition financing or related services
Purple = BMO provided both transaction advisory services and acquisition financing or related services
Mid-Continent Snapshot
TRANSACTION ACTIVITY (EXCLUDES CORPORATE DEALS)
PERMITTING ACTIVITY BY MONTH
DIFFERENTIALS RIG COUNT
Source: BMO Transaction Database, Baker Hughes, BMO Commodity Products Group, Bloomberg, Drilling Info, PLS
Note: Current quarter’s data is through the week covered by this issue.
1. Represents total enterprise value. Excludes transactions with deal value <$20 million. 2. $/acre multiple not adjusted for value associated with production.
3. Red line denotes average since 01-Jan-18. Calculated as the weighted average of each quarter’s transactions.
4. Production valued at $45,000/boepd in 2014, $30,000/boepd in 2015, $35,000/boepd in 2016 & 2017, $40,000/boepd in 2018 & 2019, and $30,000/boepd in 2020.
TRANSACTION PRODUCTION MULTIPLES(3) TRANSACTION ADJUSTED NET ACRE MULTIPLES(3,4)
[TBU]
[TBU]
[TBU]
[TBU]
[TBU]
[TBU]
[TBU]
[TBU]
[TBU]
[TBU]
GROSS PRODUCTION (THROUGH 31-MAR-20)
[TBU]
[TBU]
[TBU]
15
July 27, 2020
0%
5%
10%
15%
20%
--
10
20
30
40
Jan-15 Jan-16 Jan-17 Jan-18 Jan-19 Jan-20
Deep Water Shelf % of Total Rigs
Item Value Wkly Change Last Week Item Value Wkly Change Last Week
Rig Count 12 -- 12 Oil Differential $1.90 $0.30 $1.60
Permitting Activity 8 1 7 Gas Differential -- -- --
-$10.00
-$5.00
$0.00
$5.00
$10.00
2015 2016 2017 2018 2019 2020
-$10.00
-$5.00
$0.00
$5.00
$10.00
$ /
mm
btu
$ /
bb
l
LLS Henry Hub
3026
2220
22
16
22 2320
1115
10
20
Jul-19 Sep-19 Nov-19 Jan-20 Mar-20 May-20 Jul-20
--
$10
$20
$30
$40
1Q
15
2Q
15
3Q
15
4Q
15
1Q
16
2Q
16
3Q
16
4Q
16
1Q
17
2Q
17
3Q
17
4Q
17
1Q
18
2Q
18
3Q
18
4Q
18
1Q
19
2Q
19
3Q
19
4Q
19
1Q
20
2Q
20
0 0 1 0 0 0 2 1 0 0 0 1 2 1 0 1 1 2 0 2 0 1
$ /
bo
e
# Deals
$14.65
--
$15,000
$30,000
$45,000
$60,000
1Q
15
2Q
15
3Q
15
4Q
15
1Q
16
2Q
16
3Q
16
4Q
16
1Q
17
2Q
17
3Q
17
4Q
17
1Q
18
2Q
18
3Q
18
4Q
18
1Q
19
2Q
19
3Q
19
4Q
19
1Q
20
2Q
20
0 0 1 1 0 0 2 0 0 0 0 1 2 2 2 1 1 3 0 2 0 1
$ /
bo
e/d
# Deals
$29,229
Ann'd
Date Buyer Seller Asset Description Value(2)
Proved
Multiple
Prod.
Multiple Net Acres
($mm) ($/boe) ($/boe/d) ($/acre)(3)
22-Jun-20 Talos Energy Castex Energy Gulf of Mexico assets $65 $3.69 $10,156 n.a.
12-Dec-19 W&T Offshore ConocoPhillips Deepwater GOM assets $20 $4.88 $8,696 n.a.
10-Dec-19 Talos Energy Multiple GOM assets and exploration prospects $640 $14.71 $33,684 n.a.
27-Jun-19 W&T Offshore ExxonMobil Mobile Bay assets $200 $2.70 $10,101 n.a.
13-May-19 Equinor Shell 22.45% WI in Caesar-Tonga Field $965 n.a. $60,313 n.a.
Mean $378 $6.49 $24,590 n.a.
Median $200 $4.29 $10,156 n.a.
Blue = BMO provided transaction advisory services Green = BMO provided acquisition financing or related services
Purple = BMO provided both transaction advisory services and acquisition financing or related services
Gulf of Mexico Snapshot
PERMITTING ACTIVITY BY MONTH(1)
DIFFERENTIALS RIG COUNT
Source: BMO Transaction Database, Baker Hughes, BMO Commodity Products Group, Bloomberg, Drilling Info, PLS
Note: Current quarter’s data is through the week covered by this issue.
1. Permits include directional and unidentified drilling permits. 2. Represents total enterprise value. Excludes transactions with deal value <$20 million.
3. $/acre multiple not adjusted for value associated with production.
4. Red line denotes average since 01-Jan-18. Calculated as the weighted average of each quarter’s transactions.
GROSS PRODUCTION (THROUGH 31-MAR-20)
TRANSACTION ACTIVITY (EXCLUDES CORPORATE DEALS)
TRANSACTION PRODUCTION MULTIPLES(4) TRANSACTION PROVED RESERVE MULTIPLES(4)
[TBU]
2,000
2,500
3,000
3,500
4,000
4,500
1,200
1,400
1,600
1,800
2,000
2,200
Jan-15 Oct-15 Jul-16 Apr-17 Jan-18 Oct-18 Jul-19
mm
cf/
d
mb
bl/
d
Oil Gas
1,937
2,893
[TBU]
[TBU]
[TBU]
[TBU]
[TBU]
[TBU]
[TBU]
[TBU]
[TBU]
[TBU]
16
July 27, 2020
Upcoming Industry Events
Disclaimer: The foregoing links are for convenience only and relate to materials that were not prepared or reviewed by BMO Capital Markets. BMO Capital Markets takes
no responsibility for and makes no representations with respect to the contents thereof. These materials may be inconsistent with the views of BMO Capital Markets.
Click event to open
2021
November 2020 Nov 3-4 Executive Oil Conference & Exhibition (Midland)
Nov 17 Houston Producers Forum Luncheon
Nov 20 ADAM-Houston Monthly Luncheon
April 2021 Apr 14 IPAA Leaders in Industry Luncheon
Apr 16 ADAM-Houston Monthly Luncheon
Apr 19-20 Mineral & Royalty Conference
Apr 19-21 DUG Permian (Fort Worth)
Apr 20 Houston Producers Forum Luncheon
Apr 27-30 SPE Western Regional Meeting
Apr 29 SPE Permian Basin Summit
August 2020 Aug 10 Mineral & Royalty Conference (virtual)
Aug 11-27 Summer NAPE (virtual)
Aug 17-19 Enercom Oil & Gas Conference (virtual)
Aug 18-19 DUG Midcontinent (virtual)
Aug 20 SPE Emerging Engineers Symposium
Aug 29-Sep 2 SPE Improved Oil Recovery Conference
September 2020 Sep 8-10 DUG Permian Basin & Eagle Ford (San Antonio)
Sep 15 Houston Producers Forum Luncheon
Sep 18 ADAM-Houston Monthly Luncheon
October 2020 Oct 11-14 SPE Technical Conference and Exhibition
Oct 13-14 DUG Haynesville (Shreveport)
Oct 14-15 OilComm Conference & Exposition
Oct 16 ADAM-Houston Monthly Luncheon
Oct 20 Houston Producers Forum Luncheon
Oct 27-28 A&D Strategies and Opportunities Conference
December 2020 Dec 1-3 DUG East (Pittsburgh)
Dec 3 IPAA Texas Hold'Em Tournament
Dec 15 Houston Producers Forum Luncheon
January 2021 Jan 13 IPAA Leaders in Industry Luncheon
Jan 15 ADAM-Houston Monthly Luncheon
Jan 18-22 API E&P Winter Standards Meeting
Jan 19 Houston Producers Forum Luncheon
Jan 21 IPAA Private Capital Conference
February 2021 Feb DUG Energy ESG Conference
Feb 2-4 SPE Hydraulic Fracturing Technology Conference
Feb 8-12 NAPE Summit
Feb 10 IPAA Leaders in Industry Luncheon
Feb 16 Houston Producers Forum Luncheon
Feb 19 ADAM-Houston Monthly Luncheon
Feb 21-24 Energy in Data Conference
March 2021 Mar 1-3 SPE Reservoir Simulation Conference
Mar 10 IPAA Leaders in Industry Luncheon
Mar 16 Houston Producers Forum Luncheon
Mar 19 ADAM-Houston Monthly Luncheon
Mar 25-26 DUG Bakken and Rockies (Denver)
May 2021 May 3-6 Offshore Technology Conference
May 12 IPAA Leaders in Industry Luncheon
May 18 Houston Producers Forum Luncheon
May 21 ADAM-Houston Monthly Luncheon
May 26-27 DUG Haynesville (Shreveport)
17
July 27, 2020
SCOOP/STACK/Merge
DJ-Niobrara
Eagle Ford
Haynesville
Granite Wash
GOM
Permian
Marcellus
Utica
Williston
Gulf Coast Onshore
Piceance
Powder River Green River
Legend
Current
Change
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Source of rig count stats: Baker Hughes
Rig Count Summary MAPS IN
MASTER VIEW
Contacts
Disclaimer
Jason Martinez
MD & Head of U.S. A&D
713-546-9771
Howard Barnwell
MD & Transactions Mgr.
713-546-9767
Rob Priske
MD & Transactions Mgr.
713-546-9727
Dan Schockling
MD & Head of Commercial
713-518-1223
Michael Hackett
Vice President
Marian Yu
Associate
Aaron Moeller
Associate
BMO uses updated basin outlines, and the resulting rig counts, to more accurately represent current basin knowledge. The data below reflect these changes
and is different than those shown by Baker Hughes. The totals are the same.
126
2
10
--
6
--
25
(2)4
--
12
--
1
18
(1)
32
--
13
--
2
(2)
1
--
--
--1
--
Michelle Tankimovich
Analyst
This
Week Change
Last
Week
Last
Year
Total Rigs 251 (2) 253 946
Oil 181 1 180 776
Gas 68 (3) 71 169
Miscellaneous 2 -- 2 1
Directional 22 (1) 23 67
Horizontal 215 -- 215 823
Vertical 14 (1) 15 56
Basin
Permian 126 2 124 443
SCOOP/STACK/Merge 8 (1) 9 76
Granite Wash 1 1 -- 8
Eagle Ford 13 -- 13 81
Haynesville 32 -- 32 58
Marcellus 25 (2) 27 57
Utica 6 -- 6 15
Williston 10 -- 10 47
DJ-Niobrara 4 -- 4 29
Green River 1 -- 1 17
Powder River -- -- -- 23
Piceance 1 -- 1 6
Gulf Coast Onshore 2 (2) 4 19
GOM 12 -- 12 23
Alaska 3 -- 3 9
Other 7 -- 7 35
Mid-Con 1 -- 1 15
Rockies -- -- -- 2
Western 5 -- 5 18
Eastern 1 -- 1 --
[TBU]
[TBU]