prompt oil price ($/bbl) $54.18 ($2.05) (3.6% ... · alberta plans to allow oil companies to exceed...
TRANSCRIPT
1
November 4, 2019
IndicatorCurrent
Value
Week's
Change
%
Change Direction
Prompt Oil Price ($/bbl) $54.18 ($2.05) (3.6%)
Prompt Gas Price ($/mmbtu) $2.63 $0.31 13.4%
Wkly Trans. Value ($mm) -- ($150) (100%)
Wkly Trans. Count -- (2) (100%)
US Rig Count 822 (8) (1.0%)
US Oil Prod'n (mmbbl/d) 12.6 -- --
US Gas Prod'n (bcf/d)(1) 111.4 2.5 2.3%
US Oil Storage (mmbbl) 438.9 5.7 1.3%
US Gas Storage (tcf) 3.7 0.1 2.5%
$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
$3.4
--
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
61% 83% 74% 79% 39% 52% 62% 71% 93% 24% 68% 82% 91% 64% 46% 93% 51% 95% 74% 66%
Nu
mb
er
of
Tra
ns
ac
tio
ns
Tra
ns
ac
tio
n V
alu
e (
$b
n)
Asset Corporate Number of Transactions
% Oil% Oil% Oil
$64.3
Encana Corporation announced its intention to establish
corporate domicile in the U.S. and rebrand under the name
Ovintiv Inc.
Debt
Markets
Three issuers priced three tranches for $4 billion in proceeds
U.S. high yield funds reported an inflow of $940 million
ETFs reported an inflow of $860 million, while mutual funds reported an inflow of $80 million
High yield index yield was 5.88%; high yield energy index yield was 9.53%
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 Aug 2019.
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) underperformed last week (1.5)% vs. SPX(2) 0.9%
The major U.S. equity indexes finished mostly higher last week. Financials, industrials, materials, and
tech were all up. Consumer staples, consumer discretionary, and real estate finished down
Equity
Markets
Oil ended last week down. Oil markets were affected by continued turmoil in the Middle East. Escalating
protests in Iraq and Lebanon likely added some additional risk premium in prices. It was also reported
that Saudi Arabia’s Energy Minister is ready to make deeper cuts in oil output than the OPEC+
agreement call for, but this was not from Saudi officials directly. The build in overall crude oil inventories
last week of 5.7 mmbbls surprised the market. TC Energy’s Keystone pipeline was shut after a spill in
North Dakota. The spill occurred ahead of the split where crude flows either to Patoka or Cushing.
Alberta plans to allow oil companies to exceed their output caps if the excess output is shipped by rail,
starting in December. The near-term contract closed down $2.05, or 3.6%, at $54.18
Gas ended last week up. The November contract expired. The extreme cold forecasted to drop into the
Mid-Continent was a big driver of front-loaded price movements. However, if the cold does not
materialize, it will create a good selling opportunity since the market is pricing polar vortex type conditions
in. The near-term contract closed up $0.31, or 13.4%, at $2.63
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 October 25, 2019 to October 31, 2019
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
Saudi Aramco announced that it is producing more than 9.9 mmbbl/d of crude as it fully recovers from attacks much sooner than
expected. Overall market decline has been driven by the U.S.-China trade war as well as concerns that demand will weaken despite
the return of Saudi supplies after last month’s attack on two oil processing centers that briefly halted more than 5% of the world’s oil
production. Ecuador announced that it will leave OPEC.
Longer term forecasts indicate normal to above normal weather in the second half of October. Gas storage numbers indicated the
market is still very oversupplied despite warmer weather from the mid-Atlantic to Texas. Most analysts believe that the summer heat is
almost done for the year. However, with production at near record levels, it will take prolonged cold temperatures to make a large
difference
Continued downward momentum combined with production destined for new record highs affected the markets.
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2
November 4, 2019
$36.6 $35.5 $40.6
$18.6
$14.5 $16.4
$28.0 $67.9 $51.1 $51.9
$68.6
$86.5
2016 2017 2018 2019
1,057 1,380 762 173
Asset Corporate
Deal Count
y = 30.509e-0.068x
R² = 0.3414
--
$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
Ann'd
Date Buyer Seller Area Asset Description Value (1)
Proved
Multiple
Prod.
Multiple Net Acres
($mm) ($/boe) ($/boe/d) ($/acre)
21-Oct-19 Heritage Resources Inc Range Resources Marcellus/Utica Southw est Applachia ORRIs $150 n.a. $92,025 nmf
30-Sep-19 Viper Energy Partners Undisclosed Seller Permian 1,045 net royalty acres in Permian $168 n.a. $143,959 nmf
27-Sep-19 Contango White Star Petroleum LLC Mid-Continent 314,800 net acres in Mid-Con $133 $1.57 $8,833 $421
13-Sep-19 Viper Energy Partners Santa Elena Minerals LP Permian 1,358 net royalty acres in Permian $150 n.a. $107,143 nmf
12-Sep-19 Contango Will Energy Corporation Mid-Continent TX Panhandle, W. Anadarko, and N.LA $23 n.a. $16,429 $144
03-Sep-19 Spur Energy Partners Concho Resources Inc Permian ~70,000 net acres in Eddy and Lea, NM $925 n.a. $37,000 $13,214
03-Sep-19 Undisclosed Buyer Crescent Point Other Rockies 224,000 net undeveloped acres in Uinta $525 n.a. $32,051 $2,344
28-Aug-19 Scout Energy Partners Riviera Resources Inc Mid-Continent Hugoton Basin assets $295 $2.30 $17,020 $295
27-Aug-19 Hilcorp Energy Co BP Alaska Alaskan area exit $5,600 n.a. $75,676 n.a.
06-Aug-19 Undisclosed Buyer Pioneer Permian 3,300 net acres in Martin County $66 n.a. n.a. $20,000
Blue = BM O provided transaction advisory services Green = BM O provided acquisit ion f inancing or related services
Purple = BM O provided both transaction advisory services and acquisit ion f inancing or related services
Public Company
42%
PE / PE-Backed
16%
Private11%
Other31%
LTM By Buyer Type
Oil55%Gas
45%
LTM By Commodity
Permian26%
Rockies (ex. Bakken)
8%
Bakken4%
Appalachia5%
Mid-Con15%
Eagle Ford4%
Ark-La-Tex5%
Gulf of Mexico5%
Other28%
LTM By Region
R / P
Sales Value /
Proved Reserves
(15:1)
(ratio) ($ / boe) ($ / mcfe)
8x $17.57 $1.17
10x $15.33 $1.02
15x $10.88 $0.73
20x $7.73 $0.52
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. 65 transactions from January 2015 to 2019 with transaction value >$20mm. Adjusted for changes in price outlooks. Recalculated boe reserves are on a 15:1
(gas:oil) basis. Acreage transactions excluded by using deals with PDP of >= 40% of total proved.
4. Year-to-date data is through this week’s date for each respective year.
(2) (2) (2)
Confirm number of transactions weekly --->
YTD Deal Activity ($bn)(4)
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3
November 4, 2019
10/31/2019
Appalachia 3
Ark-La-Tex 5
Bakken 7
Eagle Ford 13
Mid-Con 10
Other 13
Permian 22
Rockies 11
84
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
Appalachia
3 Deals
Mid-Con
10 Deals
Eagle Ford
13 Deals
Permian
22 Deals
Other
13 Deals
Rockies
11 Deals
(Click headline to link to the full article)
M&A&D Headlines
Bakken
7 Deals
Ark-La-Tex
5 Deals
BMO Deals (Status)
Siltstone Appalachia (In Market) – See page 6
Oil Posts Biggest Weekly Gain in Five Weeks on
Trade Optimism
Asian Gas Demand Looks Strong, EIA Assures
Big Oil Gets Bigger
BP Profit Beats as Strong Refining Offsets Lower Oil
Price
Conoco Generates Almost $1 Billion of Free Cash
Flow in Q3
Halliburton and Repsol Sign E&P Cloud Data
Management Agreement
Encana to Establish Corporate Domicile in the U.S.
and Change Its Name to Ovintiv Inc.
Talos Energy Announces Full Year 2019 Operating
and Financial Guidance (includes A&D
announcement)
BMO Deals in Market
Caerus Piceance Basin – See page 4
Siltstone Appalachia – See page 5
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4
November 4, 2019
Caerus Operating, LLC (“Caerus”) and its subsidiary, Grand
Valley Mineral Company LLC, are offering for sale select
producing mineral and overriding royalty interests in the
Piceance Basin
Opportunity to acquire ~4,150 developed mineral acres in
the Piceance Basin located in Garfield County, Colorado
Offering includes mineral and overriding royalty
interests in the Areas of Interest: East Fork, Battlement
Mesa, and Mamm Creek
ORRI interest in ~1,650 wells
All assets are held-by-production (“HBP”)
Future acquisition opportunities are expected as the
company owns ~45,000 net mineral acres in the basin
and is actively acquiring and developing additional
interests
~4 mmcfe/d (95% gas) Q4 2019E net production from
>2,200 gross producing wells
Q4 2019E annualized cash flow of >$3 million
Source: Caerus 2019 Piceance Minerals Divestiture announcement
Currently on the Market from BMO: Caerus Piceance Minerals Divestiture
ASSET HIGHLIGHTS
ASSET OVERVIEW PROCESS OVERVIEW
VDR available November 2019 with ARIES model and LOS
Contact Chelsea Neville at [email protected] or
713-546-9703 for a Confidentiality Agreement, access to the
VDR, and/or to request a data room presentation
Grand Valley Minerals
Areas of Interest
Piceance
Represents One
of the Premier
U.S. Onshore
Natural Gas
Basins
One of the largest natural gas accumulations in North America, with an estimated 300 tcf gas-in-place
Drilling activity began to increase in 2017 with operators primarily focused on directional Mesaverde exploitation
16,000+ wells drilled to-date in the basin with cumulative production > 8 tcf
3,000’ – 5,000’ of vertical pay in the Williams Fork sands within the Mesaverde Group
Large Minerals
and ORRI Position
in the Piceance
Basin
~4,150 net mineral acres in Garfield County, CO and ORRI interest in ~1,650 wells
Average NRI of 2.7%
All assets are HBP and largely developed
Stable Production
and Cash Flow
Q4 2019E annualized cash flow of >$3 million
While asset is largely producing, any future developments would be free of capital contributions given leased mineral and
ORRI nature
Cost free royalties enhance economics by improving realizations
~4 mmcfe/d (95% gas) Q4 2019E net production
Low decline of 8% provides predictable production stream, as wells were generally developed between 2006 and 2012
Low concentration risk as properties contain interests in >2,200 gross wells
Forecast utilizes key decline curve parameters based off year-end NSAI reserves
Caerus is a Top
Piceance
Operator
Caerus is the second largest producer in the Piceance Basin and the second largest mineral owner
Position located in the core of the basin with ample takeaway options
Actively involved in acquisitions and development of the basin with 2 rigs currently running
Since 2014, Caerus has drilled and completed >350 Williams Fork wells
Caerus formed Grand Valley Mineral in 2018 to manage existing minerals and, alongside its partners, acquire additional
minerals
Caerus owns a total of ~45,000 net mineral acres in the Piceance with the majority in the North Parachute Ranch area
90% of total minerals operated by Caerus
ASSET MAP (PICEANCE BASIN – GARFIELD COUNTY)
5
November 4, 2019
Opportunity to acquire a substantial portfolio of mineral and
overriding royalty assets in the core of the Utica, Marcellus,
and Upper Devonian
55,329 net royalty acres(1), 1,866 ORRI acres(1), and
1,760 additional leased working interest acres
Low concentration risk, with interest in greater than 675
currently producing wells across 20 counties in OH, PA, and
WV
March 2019 production of 16.8 net mmcfe/d (91% gas)
with drilling inventory consisting of more than 3,800
locations
Siltstone has exposure to a significant number of future
development locations in core Utica
Siltstone continues to actively acquire mineral positions
Source: Siltstone 2019 Appalachia Divestiture announcement
1. Net royalty acres normalized to 1/8th royalty.
2. March 2019 daily production. Upper Devonian production represents <1% of total production.
Currently on the Market from BMO: Siltstone Appalachia Minerals Divestiture
ASSET HIGHLIGHTS
ASSET OVERVIEW ASSET MAP
VDR available now
Contact Sandra Ramsey at [email protected]
or 713-518-1187 for a Confidentiality Agreement, access to
the VDR, and/or to request a data room presentation
PROCESS OVERVIEW
Acreage concentrated in the core of the play
Exposure to premier acreage within areas of activity for major Appalachian operators including Antero, Ascent, Encino, EQT,
and Gulfport, plus well-capitalized operators including Chevron, ExxonMobil, and Shell
Increasing development activity due to unrestricted market access following recent completion of midstream de-bottlenecking
programs
Substantial free cash flow generation
Royalty revenue from interest in greater than 675 producing horizontal wells
Lease extensions and renewals provide additional revenue source
Significant potential upside
Portfolio contains repeatable drilling inventory of highly economic locations with line of sight to more than 150 DUCs/PUDs
Wells spud on Siltstone acreage increasing annually
Comprehensive land and title documentation (both digital and hard copy)
52% in
Belmont and
Jefferson, OH
42% in
Washington and
Greene, PA
Concentrated in most
economic and actively
developed areas
Elk
Erie
York
Tioga
Erie
Potter
Steuben
Centre
Oneida
Berks
Butler
Bradford
Kent
Lycoming
Bedford
Clinton
McKeanWarren
Clearfield
Augusta
Allegany
Blair
Indiana
Crawford
Luzerne
Somerset
Stark
Otsego
Wayne
Cattaraugus
Randolph
Bath
Fayette
Perry
Lancaster
Hardy
Mercer
Kanawha
Franklin
Chester
Garrett
Sussex
Cayuga
Tioga Delaware
Oswego
Broome
Ontario
Knox
Wayne
Chautauqua
Monroe
Chenango
Grant
Clarion
Preston
Schuylkill
Gallia
Cambria
Wayne
Monroe
Herkimer
Pike
Pocahontas
Lorain
Madison
Huntingdon
Onondaga
Venango
Greene
Perry
Clay
Nicholas
Allegheny
Adams
Fauquier
Trumbull
Washington
Meigs
Roane
Athens
Westmoreland
Cecil
Jefferson
Ashtabula
Frederick
Mifflin
Fulton
Rockingham
Licking
Noble
Pendleton
Carroll
Louisa
Yates
Fayette
Lewis
Wayne
Forest
Niagara
Webster
Braxton
Dauphin
Ritchie
Belmont
Mason
Wyoming
Wood
Armstrong
Portage
Baltimore
Livingston
Tucker
Beaver
Caroline
Lincoln
Albemarle
Carroll
Monroe
Boone
Susquehanna
Fairfax
Loudoun
Page
Hampshire
Cortland
Charles
Kent
Harford
Muskingum
Wirt
Medina
Sullivan
Jackson
Holmes
Morgan
Bucks
Summit
Washington
Guernsey
Genesee
Juniata
Union
Tyler
Carbon
Coshocton
Wetzel
Ashland
Greenbrier
Columbia
Tompkins
Lehigh
Gilmer
Geauga
Dorchester
Orleans
Vinton
Harrison
Upshur
Allegany
Harrison
Salem
Lake
Tuscarawas
Highland
Snyder
Orange
Frederick
Marion
Putnam
Cuyahoga
Cumberland
Jefferson
Columbiana
Cabell
Mineral
Wyoming
Cameron
Mahoning
Barbour
Culpeper
Chemung
Lebanon
Huron
Montgomery
Washington
Schuyler
Hocking
Wicomico
Essex
Lawrence
Marshall
Berkeley
Montgomery
Stafford
Howard
Monongalia
Morgan
Warren
Taylor
Clarke
Erie
Ohio
Doddridge
Ohio
Pennsylvania
New York
Virginia
West Virginia Maryland
Pad / Well Name OperatorAvg. Peak
(mmcfe/d)
Jack Hamilton E SMF JF Ascent 29.1
Bounty Hunter EQT 21.7
Cosgray EQT 22.0
Quarto Mining Co. CNX 20.9
Coastal Forest Res. Co. Antero 22.3
My TB Investments 25H Shell 16.3
1
2
3
4
5
6
6
1
2
3 4
5
OH31,674
PA14,190
WV9,465
Net Royalty Acres
by State(1)
OH84%
PA11%
WV5%
Production
by State(2)
Production
by Operator(2)
Utica86%
Marcellus14%
Production
by Formation(2)
EQT22%
Encino21%
GPOR21%
Ascent13%
AR6%
CNX5%
MR4%
SWN2%
Other6%
6
November 4, 2019
Historical Prices as of 31-Oct-19 Close ($/gal)
NGLs Current Last Wk. 6 Mo. Ago 1 Yr. Ago
Ethane $0.20 $0.18 $0.24 $0.36
Propane $0.51 $0.46 $0.63 $0.85
Butane $0.64 $0.59 $0.65 $0.92
Iso-butane $0.81 $0.78 $0.74 $0.96
Pentane+ $1.12 $1.16 $1.30 $1.34
25%
35%
45%
55%
65%
Oct-16 Apr-17 Oct-17 Apr-18 Oct-18 Apr-19 Oct-19
% o
f W
TI
NGL as % of WTI
NYMEX Gas Futures as of 31-Oct-19 Close ($/mmbtu)
Period(1) Current Last Wk. 6 Mo. Ago 1 Yr. Ago
12 Mo. Strip $2.48 $2.37 $2.72 $2.87
2019 $2.63 $2.39 $2.68 $2.84
2020 $2.48 $2.39 $2.70 $2.68
2021 $2.47 $2.43 $2.66 $2.61
2022 $2.64 $2.60 $2.83 $2.74
2023 $2.64 $2.60 $2.83 $2.74
$1
$2
$3
$4
$5
Oct-18 Apr-19 Oct-19 Apr-20 Oct-20
($/m
mb
tu)
NYMEX WTI Futures as of 31-Oct-19 Close ($/bbl) NYMEX Gas Futures as of 31-Oct-19 Close ($/mmbtu)
Period(1) Current Last Wk. 6 Mo. Ago 1 Yr. Ago
12 Mo. Strip $53.06 $54.85 $62.97 $65.80
2019 $54.18 $56.23 $63.68 $65.80
2020 $52.83 $54.58 $60.73 $64.07
2021 $50.78 $52.11 $57.29 $61.48
2022 $50.32 $51.36 $55.20 $59.09
2023 $50.58 $51.39 $54.22 $57.16
$20
$30
$40
$50
$60
$70
$80
Oct-18 Apr-19 Oct-19 Apr-20 Oct-20
($/b
bl)
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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Historical Prices as of 03-Oct-19 Close ($/gal)
NGLs Current Last Wk. 6 Mo. Ago 1 Yr. Ago
Ethane $0.20 $0.19 $0.21 $0.54
Propane $0.43 $0.47 $0.62 $1.06
Butane $0.54 $0.55 $0.62 $1.25
Iso-butane $0.80 $0.84 $0.76 $1.30
Pentane+ $1.06 $1.15 $1.28 $1.70
NYMEX Gas Futures as of 03-Oct-19 Close ($/mmbtu)
Period(1) Current Last Wk. 6 Mo. Ago 1 Yr. Ago
12 Mo. Strip $2.41 $2.46 $2.85 $2.93
2019 $2.41 $2.49 $2.80 $2.86
2020 $2.43 $2.47 $2.75 $2.65
2021 $2.45 $2.46 $2.67 $2.59
2022 $2.63 $2.64 $2.84 $2.72
2023 $2.63 $2.64 $2.84 $2.72
NYMEX WTI Futures as of 03-Oct-19 Close ($/bbl) NYMEX Gas Futures as of 03-Oct-19 Close ($/mmbtu)
Period(1) Current Last Wk. 6 Mo. Ago 1 Yr. Ago
12 Mo. Strip $51.16 $54.32 $61.90 $75.14
2019 $52.41 $56.35 $62.34 $74.88
2020 $50.72 $53.60 $59.83 $70.56
2021 $49.42 $51.37 $56.82 $66.52
2022 $49.52 $51.05 $54.73 $63.42
2023 $50.16 $51.43 $53.72 $61.27
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7
November 4, 2019
AECO
Northern
California
Sumas
Southern
California
El Paso - SJ
Waha
HSC
Henry Hub
Panhandle
CIG Chicago
Dominion
Transco
Clearbrook
Midland
Cushing
St. James
(LLS)
East Coast
U.S. (Brent)
Midland Sweet-
Sour Spread
EMS
NATURAL GAS PRICING & DIFFERENTIALS TO HENRY HUB ($ / MMBTU) – AS OF 31-OCT-19
Commodity Prices (cont’d)
OIL PRICING & DIFFERENTIALS TO CUSHING WTI ($ / BBL) – AS OF 31-OCT-19
Legend
Price
Diff.
Legend
Price
Diff.
Source: BMO Commodity Products Group, Bloomberg
Note: Prices and differentials are for prompt month futures except for Clearbrook which is based on spot prices.
MAPS IN
MASTER VIEW
TBU
TBU
$2.63
TBU
TBU
TBU
TBU
TBU
TBU
$2.23
($0.40)
$2.25
($0.38)
$3.48
$0.85
$2.32
($0.31)
$2.75
$0.12
$2.29
($0.34)
$60.23
$6.05
$57.39
$3.21
$2.95
$0.32
$54.18
$52.33
($1.85)
($0.46)
$3.17
$0.54
$46.78
($7.40)
TBU
TBU
TBU
$55.04
$0.86
$2.19
($0.44)
$2.52
($0.11)
$2.01
($0.62)
$1.44
($1.19)
8
November 4, 2019
Item Value Wkly Change Last Week Item Value Wkly Change Last Week
Rig Count 416 (1) 417 Oil Differential $0.70 $0.05 $0.65
Permitting Activity 173 29 144 Gas Differential ($1.80) ($0.22) ($1.59)
0%
10%
20%
30%
40%
50%
--
100
200
300
400
500
Jan-15 Jan-16 Jan-17 Jan-18 Jan-19
H V+D % of Total Rigs
-$4.80
-$3.20
-$1.60
$0.00
$1.60
Jan-15 Jan-16 Jan-17 Jan-18 Jan-19
-$18.00
-$12.00
-$6.00
$0.00
$6.00
$ /
mm
btu
$ /
bb
l
Midland Waha
5,000
7,000
9,000
11,000
13,000
15,000
1,000
1,500
2,000
2,500
3,000
3,500
4,000
4,500
Jan-15 Jul-15 Jan-16 Jul-16 Jan-17 Jul-17 Jan-18 Jul-18 Jan-19
mm
cf/
d
mb
bl/
d
Oil Gas
4,189
14,4381,212
1,010868
1,247
1,065
1,207
1,050
1,256
905765 743
596777
Oct-18 Dec-18 Feb-19 Apr-19 Jun-19 Aug-19 Oct-19
H V+D
Ann'd
Date Buyer Seller Asset Description Value(1)
Proved
Multiple
Prod.
Multiple Net Acres
($mm) ($/boe) ($/boe/d) ($/acre)(2)
30-Sep-19 Viper Energy Partners Undisclosed Seller 1,045 net royalty acres in Permian $168 n.a. $143,959 nmf
13-Sep-19 Viper Energy Partners Santa Elena Minerals LP 1,358 net royalty acres in Permian $150 n.a. $107,143 nmf
03-Sep-19 Spur Energy Partners Concho Resources Inc ~70,000 net acres in Eddy and Lea, NM $925 n.a. $37,000 $13,214
06-Aug-19 Undisclosed Buyer Pioneer 3,300 net acres in Martin County $66 n.a. n.a. $20,000
31-Jul-19 Ecopetrol Oxy Midland Basin JV $1,500 n.a. n.a. $31,559
Mean $562 n.a. $96,034 $21,591
Median $168 n.a. $107,143 $20,000
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
1 2 8 8 6 6 12 13 15 7 2 2 7 2 5 4 1 2 0 1
$ /
acre
# Deals
$26,951
--
$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
1 2 6 9 5 7 11 9 9 6 1 0 7 2 5 4 1 2 4 1
$ /
bo
e/d
# Deals
$91,724
GROSS PRODUCTION
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-17. 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, and $40,000/boepd in 2018 & 2019.
TBU
TBU
TBU
TBU
TBU
TBU
TBU
TBU
TBU
TBU
TBU
TBU
TBU
TBU TBU
TBU TBU
TBU TBU
TBU
9
November 4, 2019
Item Value Wkly Change Last Week Item Value Wkly Change Last Week
Rig Count 75 -- 75 Oil Differential $3.00 $0.40 $2.60
Permitting Activity 55 13 42 Gas Differential ($0.09) $0.01 ($0.10)
0%
5%
10%
15%
20%
--
100
200
300
Jan-15 Jan-16 Jan-17 Jan-18 Jan-19
H V+D % of Total Rigs
-$0.30
-$0.20
-$0.10
$0.00
$0.10
$0.20
$0.30
$0.40
$0.50
Jan-15 Jan-16 Jan-17 Jan-18 Jan-19
-$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
2,000
Jan-15 Jul-15 Jan-16 Jul-16 Jan-17 Jul-17 Jan-18 Jul-18 Jan-19
mm
cf/
d
mb
bl/
d
Oil Gas
1,378
7,190
402350
315
398353
472
351 401
222173 201 192 209
Oct-18 Dec-18 Feb-19 Apr-19 Jun-19 Aug-19 Oct-19
H V+D
Ann'd
Date Buyer Seller Asset Description Value(1)
Proved
Multiple
Prod.
Multiple Net Acres
($mm) ($/boe) ($/boe/d) ($/acre)(2)
17-Jul-19 Undisclosed Buyer Sundance Energy 6,100 net acres in Dimmit County $30 n.a. $28,069 $4,836
19-Nov-18 Lonestar Resources Inc Sabine Oil & Gas Corp 2,706 net acres in Eagle Ford $39 $2.98 $48,375 $14,302
20-Sep-18 WildHorse Undisclosed Seller 20,305 net Eagle Ford/Austin Chalk acres $35 n.a. n.a. $1,743
07-Sep-18 Undisclosed Buyer Viking Minerals LLC 1,191 net royalty acres in Eagle Ford $28 n.a. n.a. nmf
31-Jul-18 EP Energy Corp Undisclosed Seller Additional working interests in Eagle Ford $31 n.a. n.a. n.a.
Mean $33 $2.98 $38,222 $6,960
Median $31 $2.98 $38,222 $4,836
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
0 1 2 1 2 2 0 4 2 3 1 2 4 2 1 3 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
1 1 3 1 2 2 2 4 4 3 1 2 7 2 0 3 0 0 1 0
$ /
bo
e/d
# Deals
$78,467
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-17. 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, and $40,000/boepd in 2018 & 2019.
TRANSACTION PRODUCTION MULTIPLES(3) TRANSACTION ADJUSTED NET ACRE MULTIPLES(3,4)
GROSS PRODUCTION
TBU
TBU
TBU
TBU
TBU
TBU
TBU
TBU
TBU
TBU
TBU
TBU TBU
TBU
TBU
TBU TBU
TBU
TBU
TBU
TBU
TBU
TBU TBU
TBU
TBU
TBU
TBU
TBU
TBU
TBU TBU
TBU
TBU
TBU
10
November 4, 2019
Item Value Wkly Change Last Week Item Value Wkly Change Last Week
Rig Count 53 (1) 54 Oil Differential $3.15 $0.30 $2.85
Permitting Activity 10 2 8 Gas Differential -- -- --
0%
5%
10%
15%
20%
--
20
40
60
80
Jan-15 Jan-16 Jan-17 Jan-18 Jan-19
H V+D % of Total Rigs
--
$2.00
$4.00
$6.00
$8.00
$10.00
Jan-15 Jan-16 Jan-17 Jan-18 Jan-19
--
$2.00
$4.00
$6.00
$8.00
$10.00
$ /
mm
btu
$ /
bb
l
LLS Henry Hub
5,000
6,000
7,000
8,000
9,000
10,000
11,000
12,000
13,000
70
80
90
100
110
120
Jan-15 Jul-15 Jan-16 Jul-16 Jan-17 Jul-17 Jan-18 Jul-18 Jan-19
mm
cf/
d
mb
bl/
d
Oil Gas
77
12,226
180
115 105
174
113116 116
132
9499
181
9067
Oct-18 Dec-18 Feb-19 Apr-19 Jun-19 Aug-19 Oct-19
H V+D
Ann'd
Date Buyer Seller Asset Description Value(1)
Proved
Multiple
Prod.
Multiple Net Acres
($mm) ($/mcfe) ($/mcfe/d) ($/acre)(2)
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.
05-Sep-18 Equinor Texegy LLC 60,000 net acres in Austin Chalk $75 n.a. n.a. $1,250
Mean $308 $0.77 $2,690 $7,145
Median $100 $0.77 $2,690 $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
0 0 3 1 1 2 1 3 0 1 2 0 1 1 1 1 0 1 1 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
0 0 5 1 1 3 2 3 0 2 2 0 1 1 2 1 0 1 1 0
$ /
mcfe
/d
# Deals
$4,378
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-17. 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, and 2019.
TRANSACTION PRODUCTION MULTIPLES(3) TRANSACTION ADJUSTED NET ACRE MULTIPLES(3,4)
GROSS PRODUCTION
TBU
TBU
TBU
TBU
TBU TBU
TBU
TBU
TBU
TBU
TBU
TBU
TBU
TBU
TBU
TBU
TBU
TBU
TBU
TBU
TBU
TBU
TBU TBU
TBU
TBU
TBU
TBU
TBU
TBU
TBU TBU
TBU
TBU
TBU
TBU
TBU
TBU
TBU
TBU
TBU
11
November 4, 2019
Item Value Wkly Change Last Week Item Value Wkly Change Last Week
Rig Count 51 (2) 53 Oil Differential $6.05 $0.40 $5.65
Permitting Activity 23 (33) 56 Gas Differential ($0.88) ($0.28) ($0.61)
0%
5%
10%
15%
20%
--
50
100
150
Jan-15 Jan-16 Jan-17 Jan-18 Jan-19
H V+D % of Total Rigs
-$3.00
-$2.00
-$1.00
$0.00
$1.00
$2.00
$3.00
Jan-15 Jan-16 Jan-17 Jan-18 Jan-19
-$15.00
-$10.00
-$5.00
$0.00
$5.00
$10.00
$15.00
$ /
mm
btu
$ /
bb
l
Brent Dominion
14,000
19,000
24,000
29,000
34,000
50
70
90
110
130
150
Jan-15 Jul-15 Jan-16 Jul-16 Jan-17 Jul-17 Jan-18 Jul-18 Jan-19
mm
cf/
d
mb
bl/
d
Oil Gas
123
30,319
370
305258
397
276
382419
384334 346
303 293231
Oct-18 Dec-18 Feb-19 Apr-19 Jun-19 Aug-19 Oct-19
H V+D
Ann'd
Date Buyer Seller Asset Description Value(1)
Proved
Multiple
Prod.
Multiple Net Acres
($mm) ($/mcfe) ($/mcfe/d) ($/acre)(2)
21-Oct-19 Heritage Resources Inc Range Resources Southwest Applachia ORRIs $150 n.a. $15,337 nmf
24-Jul-19 Diversified Gas & Oil EdgeMarc Energy Holdings 12,730 net acres in Ohio Utica $50 $0.32 $769 $3,928
19-Jul-19 Multiple Range Resources Corp Southwest Applachia ORRIs $600 n.a. $15,790 nmf
30-Jun-19 Undisclosed Buyer Range Resources Corp 20,000 non-producing net acres in PA $34 n.a. n.a. $1,700
27-Mar-19 Diversified Gas & Oil HG Energy II LLC Huckleberry assets in Appalachia $400 n.a. $3,227 n.a.
Mean $247 $0.32 $8,781 $2,814
Median $150 $0.32 $9,282 $2,814
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
0 1 0 0 1 2 2 4 2 4 1 3 1 3 2 0 0 0 0 0
$ /
acre
# Deals
$564
--$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
0 1 0 0 1 2 2 3 2 5 1 4 3 4 3 1 1 0 2 1
$ /
mcfe
/d
# Deals
$5,500
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-17. 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, and 2019.
TRANSACTION PRODUCTION MULTIPLES(3) TRANSACTION ADJUSTED NET ACRE MULTIPLES(3,4)
GROSS PRODUCTION
TBU
TBU
TBU
TBU
TBU
TBU
TBU
TBU
TBU
TBU
TBU
TBU
TBU
TBU
TBU
TBU
TBU
TBU
TBU
TBU
TBU
TBU
TBU TBU
TBU
TBU
TBU TBU
TBU
TBU
TBU TBU
TBU
TBU
TBU
TBU
TBU
TBU
TBU
TBU TBU
12
November 4, 2019
Item Value Wkly Change Last Week Item Value Wkly Change Last Week
Rig Count 53 -- 53 Oil Differential ($1.85) $0.40 ($2.25)
Permitting Activity 16 (19) 35 Gas Differential ($0.57) ($0.22) ($0.35)
0%
5%
10%
15%
20%
--
50
100
150
200
Jan-15 Jan-16 Jan-17 Jan-18 Jan-19
H V+D % of Total Rigs
-$1.00
-$0.50
$0.00
$0.50
Jan-15 Jan-16 Jan-17 Jan-18 Jan-19
-$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
800
900
1,000
1,100
1,200
1,300
1,400
1,500
Jan-15 Jul-15 Jan-16 Jul-16 Jan-17 Jul-17 Jan-18 Jul-18 Jan-19
mm
cf/
d
mb
bl/
d
Oil Gas
1,421
2,941
201
12896
133114 144 138 145 144 154
137110
134
Oct-18 Dec-18 Feb-19 Apr-19 Jun-19 Aug-19 Oct-19
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
--
$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
0 0 1 2 0 0 2 3 1 0 3 2 0 5 2 0 0 1 0 0
$ /
acre
# Deals
$1,751
--
$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
0 1 1 4 0 2 3 3 0 1 3 3 0 6 3 0 0 1 0 0
$ /
bo
e/d
# Deals
$45,752
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-17. 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, and $40,000/boepd in 2018 & 2019.
TRANSACTION PRODUCTION MULTIPLES(3) TRANSACTION ADJUSTED NET ACRE MULTIPLES(3,4)
GROSS PRODUCTION
TBU
TBU
TBU
TBU
TBU TBU
TBU
TBU
TBU
TBU
TBU
TBU TBU
TBU
TBU
TBU
TBU
TBU
TBU
TBU
TBU
TBU
TBU TBU
TBU
TBU
TBU
TBU
TBU TBU
TBU TBU
TBU
TBU
TBU
TBU
TBU
TBU
TBU
TBU TBU
13
November 4, 2019
Item Value Wkly Change Last Week Item Value Wkly Change Last Week
Rig Count 62 1 61 Oil Differential ($1.85) $0.40 ($2.25)
Permitting Activity 25 (38) 63 Gas Differential ($0.57) ($0.22) ($0.35)
0%
5%
10%
15%
20%
--
50
100
150
Jan-15 Jan-16 Jan-17 Jan-18 Jan-19
H V+D % of Total Rigs
-$1.00
-$0.50
$0.00
$0.50
Jan-15 Jan-16 Jan-17 Jan-18 Jan-19
-$20.00
-$10.00
$0.00
$10.00
$ /
mm
btu
$ /
bb
l
Clearbrook CIG
12,000
12,500
13,000
13,500
14,000
14,500
15,000
15,500
500
600
700
800
900
1,000
Jan-15 Jul-15 Jan-16 Jul-16 Jan-17 Jul-17 Jan-18 Jul-18 Jan-19
mm
cf/
d
mb
bl/
d
Oil Gas919
13,841
689
829 812
352 402494
328
164
306 283
434327
266
Oct-18 Dec-18 Feb-19 Apr-19 Jun-19 Aug-19 Oct-19
H V+D
Ann'd
Date Buyer Seller Asset Description Value(1)
Proved
Multiple
Prod.
Multiple Net Acres
($mm) ($/boe) ($/boe/d) ($/acre)(2)
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.
31-Jan-19 Undisclosed Buyer Extraction Oil & Gas 5,000 net acres in Powder River $22 n.a. n.a. $4,480
01-Oct-18 DJR Energy LLC Encana 182,000 net acres in San Juan Basin $480 n.a. $88,889 $2,637
28-Aug-18 Vermilion Energy Inc Massif Oil & Gas LLC 55,000 acres in Powder River Basin $150 n.a. $56,604 $2,727
Mean $244 $1.57 $47,095 $3,047
Median $150 $1.57 $44,328 $2,682
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
0 0 3 3 0 1 1 0 1 0 1 5 2 0 2 1 0 0 0 0
$ /
acre
# Deals
$2,380
--$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
2 0 4 4 1 6 2 0 1 6 3 9 3 1 3 1 1 0 2 0
$ /
bo
e/d
# Deals
$36,255
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-17. 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, and $40,000/boepd in 2018 & 2019.
TRANSACTION PRODUCTION MULTIPLES(3) TRANSACTION ADJUSTED NET ACRE MULTIPLES(3,4)
GROSS PRODUCTION
TBU
TBU
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TBU TBU
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TBU TBU
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TBU TBU
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14
November 4, 2019
Item Value Wkly Change Last Week Item Value Wkly Change Last Week
Rig Count 57 (3) 60 Oil Differential -- -- --
Permitting Activity 66 -- 66 Gas Differential ($0.57) ($0.11) ($0.46)
0%
5%
10%
15%
20%
--
100
200
300
400
Jan-15 Jan-16 Jan-17 Jan-18 Jan-19
H V+D % of Total Rigs
-$1.00
-$0.75
-$0.50
-$0.25
$0.00
$0.25
Jan-15 Jan-16 Jan-17 Jan-18 Jan-19
-$1.00
-$0.75
-$0.50
-$0.25
$0.00
$0.25
$ /
mm
btu
$ /
bb
l
Cushing Panhandle
8,000
10,000
12,000
14,000
16,000
18,000
550
600
650
700
750
800
850
Jan-15 Jul-15 Jan-16 Jul-16 Jan-17 Jul-17 Jan-18 Jul-18 Jan-19
mm
cf/
d
mb
bl/
d
Oil Gas 739
13,796
405 382355
403339
435 389
298
360 343 319 340 322
Oct-18 Dec-18 Feb-19 Apr-19 Jun-19 Aug-19 Oct-19
H V+D
Ann'd
Date Buyer Seller Asset Description Value(1)
Proved
Multiple
Prod.
Multiple Net Acres
($mm) ($/boe) ($/boe/d) ($/acre)(2)
27-Sep-19 Contango White Star Petroleum LLC 314,800 net acres in Mid-Con $133 $1.57 $8,833 $421
12-Sep-19 Contango Will Energy Corporation TX Panhandle, W. Anadarko, and N.LA $23 n.a. $16,429 $144
28-Aug-19 Scout Energy Partners Riviera Resources Inc Hugoton Basin assets $295 $2.30 $17,020 $295
31-Jul-19 Continental Resources Inc Undisclosed Seller SCOOP assets $80 n.a. n.a. n.a.
08-Jul-19 NextEra Energy Inc Encana 140,000 net acres in Arkoma Basin $165 n.a. $12,857 $1,179
Mean $139 $1.93 $13,785 $510
Median $133 $1.93 $14,643 $358
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
1 3 1 2 0 3 3 2 4 1 2 1 0 0 0 1 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
1 4 1 3 1 6 3 1 4 2 4 5 2 2 5 4 2 0 4 1
$ /
bo
e/d
# Deals
$19,665
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-17. 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, and $40,000/boepd in 2018 & 2019.
TRANSACTION PRODUCTION MULTIPLES(3) TRANSACTION ADJUSTED NET ACRE MULTIPLES(3,4)
GROSS PRODUCTION
TBU
TBU
TBU
TBU
TBU TBU
TBU
TBU
TBU
TBU
TBU
TBU
TBU
TBU
TBU
TBU
TBU
TBU
TBU
TBU
TBU
TBU
TBU TBU
TBU
TBU
TBU
TBU
TBU
TBU
TBU TBU
TBU
TBU
TBU
TBU
TBU
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15
November 4, 2019
Item Value Wkly Change Last Week Item Value Wkly Change Last Week
Rig Count 21 1 20 Oil Differential $3.15 $0.30 $2.85
Permitting Activity 7 (5) 12 Gas Differential -- -- --
0%
5%
10%
15%
20%
--
10
20
30
40
Jan-15 Jan-16 Jan-17 Jan-18 Jan-19
Deep Water Shelf % of Total Rigs
--
$2.00
$4.00
$6.00
$8.00
$10.00
Jan-15 Jan-16 Jan-17 Jan-18 Jan-19
--
$2.00
$4.00
$6.00
$8.00
$10.00
$ /
mm
btu
$ /
bb
l
LLS Henry Hub
2,000
2,500
3,000
3,500
4,000
4,500
1,000
1,200
1,400
1,600
1,800
2,000
2,200
Jan-15 Jul-15 Jan-16 Jul-16 Jan-17 Jul-17 Jan-18 Jul-18 Jan-19
mm
cf/
d
mb
bl/
d
Oil Gas1,914
2,870
39
32 30 32 33
2629
26 27 29
21 23
40
Oct-18 Dec-18 Feb-19 Apr-19 Jun-19 Aug-19 Oct-19
Ann'd
Date Buyer Seller Asset Description Value(2)
Proved
Multiple
Prod.
Multiple Net Acres
($mm) ($/boe) ($/boe/d) ($/acre)(3)
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.
23-Apr-19 Murphy LLOG Bluewater LLC Mississippi Canyon & Green Canyon $1,375 $20.83 $36,184 n.a.
16-Jan-19 Talos Energy Inc Samson Energy Co LLC Non-op Gulf of Mexico working interest $30 $13.45 $17,939 n.a.
10-Oct-18 Murphy Petrobras Gulf of Mexico joint venture $900 $15.00 $21,951 n.a.
Mean $694 $13.00 $29,298 n.a.
Median $900 $14.23 $21,951 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
--
$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
0 0 1 0 0 0 2 1 0 0 0 1 2 1 0 1 1 2 0 0
$ /
bo
e
# Deals
$16.44
--
$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
0 0 1 1 0 0 2 0 0 0 0 1 2 2 2 1 1 3 0 0
$ /
bo
e/d
# Deals
$30,643
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-17. Calculated as the weighted average of each quarter’s transactions.
GROSS PRODUCTION
TRANSACTION ACTIVITY (EXCLUDES CORPORATE DEALS)
TRANSACTION PRODUCTION MULTIPLES(4) TRANSACTION PROVED RESERVE MULTIPLES(4)
TBU
TBU TBU
TBU TBU
TBU
TBU
TBU TBU
TBU
TBU TBU
TBU
TBU
TBU
TBU
TBU
TBU
TBU
TBU
TBU
TBU TBU
TBU
TBU
TBU
TBU
TBU
TBU
TBU TBU
TBU
TBU
TBU
TBU
TBU
TBU
TBU
TBU TBU
16
November 4, 2019
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
April 2019 Apr 22-23 Mineral & Royalty Conference
June 2019 Jun 24-26 IPAA Midyear Meeting
2020
Sep 8-10 DUG Eagle Ford (San Antonio)
Oct 27-28 A&D Strategies and Opportunities Conference
Nov 2-4 Executive Oil Conference & Exhibition
November 2019 Nov 4-6 Executive Oil Conference & Exhibition
Nov 13 IPAA Leaders in Industry Luncheon
Nov 15 ADAM-Houston Monthly Luncheon
Nov 19 IPAA Oil & Gas for Newcomers
Nov 19 Houston Producers Forum Luncheon
Nov 19-21 DUG Midcontinent (Oklahoma City)
Nov 20-21 11th Annual North America Assembly & Dinner
December 2019 Dec 3 SPE - Financing A Team & A Dream
Dec 5 177th OPEC Meeting
Dec 11 IPAA Leaders in Industry Luncheon
Dec 17 Houston Producers Forum Luncheon
Dec 20 ADAM-Houston Monthly Luncheon
January 2019 Jan 15 Houston Producers Forum Luncheon
Jan 25 ADAM-Houston Monthly Luncheon
Jan 24 IPAA Private Capital Conference
May 2019
May 21 Houston Producers Forum Luncheon
May 22 SPE Business Development Group Meeting
March 2019 Mar 26-28 International Petroleum Technology Conference
February 2020 Feb 3-7 NAPE Summit Week
Feb 11-12 Enercom Dallas
Feb 18-19 DUG Rockies (Denver)
Feb 19 Houston Producers Forum Luncheon
March 2020 Mar 2 Energy Capital Conference
Mar 4 Women in Energy Luncheon
Mar 5-7 IADC/SPE International Drilling Conference
Mar 9-13 Houston CERA Week
Mar 17 Houston Producers Forum Luncheon
Mar 20 ADAM-Houston Monthly Luncheon
April 2020 Apr 6-8 DUG Permian (Fort Worth)
Apr 17 ADAM-Houston Monthly Luncheon
Apr 20-22 OGIS New York
Apr 21 Houston Producers Forum Luncheon
May 2020 May 15 ADAM-Houston Monthly Luncheon
May 19 Houston Producers Forum Luncheon
May 19-20 DUG Haynesville (Shreveport)
June 2020 Jun 16 Houston Producers Forum Luncheon
Jun 16-18 DUG East (Pittsburgh)
Jun 19 ADAM-Houston Monthly Luncheon
January 2020 Jan 15 ADI Forum
Jan 17 ADAM-Houston Monthly Luncheon
Jan 21 Houston Producers Forum Luncheon
Jan 23 IPAA Private Capital Conference
July 2020 Jul 17 ADAM-Houston Monthly Luncheon
Jul 21 Houston Producers Forum Luncheon
Jul 22-24 SPE Unconventional Resources Technology
August 2020 Aug 9-12 Enercom Oil & Gas Conference
Aug 18 Houston Producers Forum Luncheon
Aug 21 ADAM-Houston Monthly Luncheon
September 2020 Sep 9 IPAA Leaders in Industry Luncheon
Sep 9-11 DUG Eagle Ford (San Antonio)
Sep 15 Houston Producers Forum Luncheon
Sep 18 ADAM-Houston Monthly Luncheon
17
November 4, 2019
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
This material is prepared by the BMO Capital Markets’ Investment and Corporate Banking Department, for distribution to BMO Capital Markets’ clientele. It is not a product of
BMO Capital Markets’ Research Department. The views of the Investment and Corporate Banking Department may differ from those of the Research Department. No part of this
publication or its contents may be copied, downloaded, stored in a retrieval system, further transmitted, or otherwise reproduced, stored, disseminated, transferred or used, in any form or
by any means by any third parties, except with the prior written permission of BMO Capital Markets.
BMO Capital Markets is a trade name used by BMO Financial Group for the wholesale banking businesses of Bank of Montreal, BMO Harris Bank N.A. (member FDIC), Bank of Montreal
Europe p.l.c, and Bank of Montreal (China) Co. Ltd and the institutional broker dealer businesses of BMO Capital Markets Corp. (Member FINRA and SIPC) in the U.S., BMO Nesbitt
Burns Inc. (Member Investment Industry Regulatory Organization of Canada and Member Canadian Investor Protection Fund) in Canada and Asia, Bank of Montreal Europel p.l.c.
(authorised and regulated by the Central Bank of Ireland) in Europe and BMO Capital Markets Limited (authorised and regulated by the Financial Conduct Authority) in the UK and
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(M-Bar roundel symbol)" is a registered trademark of Bank of Montreal, used under license. ® Registered trademark of Bank of Montreal in the United States, Canada and elsewhere. ™
Trademark of Bank of Montreal in the United States and Canada. © 2018 BMO Financial Group
Bank of Montreal or its subsidiaries (“BMO Financial Group”) has lending arrangements with, or provide other remunerated services to, many issuers covered by BMO Capital Markets.
The opinions, estimates and projections contained in this report are those of BMO Capital Markets as of the date of this report and are subject to change without notice. BMO Capital
Markets endeavors to ensure that the contents have been compiled or derived from sources that we believe are reliable and contain information and opinions that are accurate and
complete. However, BMO Capital Markets makes no representation or warranty, express or implied, in respect thereof, takes no responsibility for any errors and omissions contained
herein and accepts no liability whatsoever for any loss arising from any use of, or reliance on, this report or its contents. Information may be available to BMO Capital Markets or its
affiliates that is not reflected in this report. The information in this report is not intended to be used as the primary basis of investment decisions, and because of individual client
objectives, should not be construed as advice designed to meet the particular investment needs of any investor. This material is for information purposes only and is not an offer to sell or
the solicitation of an offer to buy any security. BMO Capital Markets or its affiliates will buy from or sell to customers the securities of issuers mentioned in this report on a principal basis.
BMO Capital Markets or its affiliates, officers, directors or employees have a long or short position in many of the securities discussed herein, related securities or in options, futures or
other derivative instruments based thereon. BMO Capital Markets may act as financial advisor and/or underwriter for the issuers mentioned herein and may receive remuneration for
same. The reader should assume that BMO Capital Markets or its affiliates may have a conflict of interest and should not rely solely on this report in evaluating whether or not to buy or
sell securities of issuers discussed herein. All values in this document are in US$ unless otherwise specified.
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
Director & 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.
416
(1)
53
--
11
--
40
(2)
22
--
21
1
5
(1)
42
(1)
53
(1)
75
--
11
(2)
3
(1)
23
--13
2
This
Week Change
Last
Week
Last
Year
Total Rigs 822 (8) 830 1,067
Oil 691 (5) 696 874
Gas 130 (3) 133 193
Miscellaneous 1 -- 1 --
Directional 53 2 51 73
Horizontal 717 (11) 728 929
Vertical 52 1 51 65
Basin
Permian 416 (1) 417 487
SCOOP/STACK/Merge 42 (1) 43 112
Granite Wash 5 (1) 6 25
Eagle Ford 75 -- 75 97
Haynesville 53 (1) 54 59
Marcellus 40 (2) 42 54
Utica 11 -- 11 20
Williston 53 -- 53 56
DJ-Niobrara 22 -- 22 27
Green River 13 2 11 18
Pow der River 23 -- 23 15
Piceance 3 (1) 4 7
Gulf Coast Onshore 11 (2) 13 26
GOM 21 1 20 18
Alaska 7 (1) 8 5
Other 27 (1) 28 41
Mid-Con 10 (1) 11 20
Rockies 1 -- 1 4
Western 15 -- 15 15
Eastern 1 -- 1 2
Michelle Tankimovich
Analyst
TBU TBU