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September 30, 2019
IndicatorCurrent
Value
Week's
Change
%
Change Direction
Prompt Oil Price ($/bbl) $56.41 ($1.72) (3.0%)
Prompt Gas Price ($/mmbtu) $2.43 ($0.11) (4.3%)
Wkly Trans. Value ($mm) -- ($150) (100%)
Wkly Trans. Count 1 -- --
US Rig Count 860 (8) (0.9%)
US Oil Prod'n (mmbbl/d) 12.5 0.1 0.8%
US Gas Prod'n (bcf/d)(1) 109.8 -- --
US Oil Storage (mmbbl) 419.5 2.4 0.6%
US Gas Storage (tcf) 3.2 0.1 3.3%
$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
$16.7
--
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
61% 83% 74% 79% 39% 52% 62% 71% 93% 24% 68% 82% 91% 64% 46% 93% 51% 95% 75%
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
Pickering Energy Partners and Henry Resources announced a
strategic joint venture to pursue acquisitions across the
Permian Basin
Tellurian and Petronet signed a memorandum of
understanding to negotiate the purchase of up to five million
tonnes of LNG through equity investment in Driftwood
Debt
Markets
Eight issuers priced eight tranches for $5.5 billion last week
U.S. high yield funds reported an outflow of $258 million
ETFs reported an outflow of $66 million while mutual funds reported an outflow of $192 million
High yield index yield was 5.82%; high yield energy index yield was 8.72%
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 June 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 (4.4)% vs. SPX(2) 1.0%
Most of the major U.S. equity indexes finished lower. Consumer staples finished up 0.5% Equity
Markets
Oil ended last week down. Tropical Storm Imelda hit Houston with more than three feet of rain and
temporarily closed some refineries in the Houston Ship Channel. There were reports that full repairs of
Saudi Arabia’s facilities would take months. However, Saudi Arabia reiterated that it will restore almost all
of the lost output by the end of September. Tensions continue to mount between the U.S. and Iran while
France and others try to calm the feud as the U.N. General Assembly gathered. Trump’s speech at the
U.N. General Assembly contained strong rhetoric regarding China and Iran. The speech also contained
anti-globalist refrains which indicated that the trade war is far from over. President Trump reiterated no
desire for using military force against Iran. The U.S. imposed new sanctions on Chinese entities accused
of skirting oil sanctions against Iran. These sanctions had the immediate effect of increasing tanker rates.
The near-term contract closed down $1.72, or 3.0%, at $56.41
Natural gas ended last week down. Storage numbers were higher than expected. Warmer-than-normal
temperatures also affected the market. The near-term contract closed down $0.11, or 4.3%, at $2.43
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 September 20 to September 26, 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!
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
Last week was another volatile week for crude oil. Inventory numbers were affected by Tropical Storm Imelda, which hit Houston with
more than three feet of rain and temporarily closed some refineries in the Houston Ship Channel. There were some reports that full
repairs of Saudi Arabia’s facilities would take months. However, Saudi Arabia reiterated that it will restore almost all of the lost output
by the end of September. Tensions continue to mount between the U.S. and Iran while France and others try to calm the feud as the
U.N. General Assembly gathered. Trump’s speech at the U.N. General Assembly contained strong rhetoric regarding China and Iran.
The speech had anti-globalist refrains which indicated that the trade war is far from over. President Trump reiterated no desire for
using military force against Iran. The U.S. imposed new sanctions on Chinese entities accused of skirting oil sanctions against Iran.
The market seemed to anticipate a tighter trading range for the next few weeks before we possibly get a glimpse of early winter
weather. In basis, it is worth highlighting weakness along the curve in Permian and Waha as GCX came online.
The U.S. Department of Defense stated that the U.S. would deploy “one patriot battery, four sentinel RADARs, and approximately 200
support personnel” to Saudi Arabia. The sanctions on certain Chinese shipping companies yesterday, including COSCO Dalian, had
the immediate effect of increasing tanker rates, especially VLCC rates, as traders scrambled to re-book ships in order to avoid
penalties. According to Bloomberg, COSCO Dalian operates 26 supertankers capable of carrying 52mm barrels total of oil. Notable
selling of MEH versus buying of Midland was in the market today which pushed Cal20 and Cal21 Mid/Cush to around +70 cents.
Storage numbers were higher than expected. Warmer-than-normal temperatures also affected the market.
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2
September 30, 2019
Permian27%
Rockies (ex. Bakken)
8%
Bakken4%
Appalachia5%
Mid-Con14%
Eagle Ford5%
Ark-La-Tex5%
Gulf of Mexico6%
Other26%
LTM By Region
Ann'd
Date Buyer Seller Area Asset Description Value(1)
Proved
Multiple
Prod.
Multiple Net Acres
($mm) ($/boe) ($/boe/d) ($/acre)
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
31-Jul-19 Continental Resources Inc Undisclosed Seller Mid-Continent SCOOP assets $80 n.a. n.a. n.a.
31-Jul-19 Ecopetrol Oxy Permian Midland Basin JV $1,500 n.a. n.a. $31,559
31-Jul-19 Undisclosed Buyer Whiting Petroleum Multi-Region 6,800 net acres in non-op assets $53 n.a. $75,391 $7,794
Blue = BMO provided transaction advisory services Green = BMO provided acquisition financing or related services
Purple = BMO provided both transaction advisory services and acquisition financing or related services
R / P
Sales Value /
Proved Reserves
(15:1)
(ratio) ($ / boe) ($ / mcfe)
8x $17.81 $1.19
10x $15.54 $1.04
15x $11.03 $0.74
20x $7.84 $0.52
y = 30.926e-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
$27.6 $32.9 $38.3
$18.1
$12.1 $16.4
$22.2 $64.7 $39.7
$49.3
$60.5
$82.7
2016 2017 2018 2019
851 1,241 721 159
Asset Corporate
Deal Count
Oil61%
Gas39%
LTM By Commodity
Public Company
44%
PE / PE-Backed
17%
Private10%
Other29%
LTM By Buyer Type
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
September 30, 2019
9/23/2019
Appalachia 3
Ark-La-Tex 5
Bakken 6
Eagle Ford 12
Mid-Con 6
Other 13
Permian 19
Rockies 9
73
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
6 Deals
Eagle Ford
12 Deals
Permian
19 Deals
Other
13 Deals
Rockies
9 Deals
(Click headline to link to the full article)
M&A&D Headlines
Bakken
6 Deals
Ark-La-Tex
5 Deals
BMO Deals (Status)
Siltstone Appalachia (In Market) – See page 6
The $47 Trillion Death Sentence For Oil & Gas
Saudi Oil Capacity Recovering From Attacks Faster
Than Expected
Texas Oil and Gas Activity Declines in Third Quarter
Permian 'Child' Wells May Cut Oil Recovery by 20%,
Bank Says
'A Muddy Mess.' Ill. Landowners Fight FERC Over
Pipeline
Tellurian and Petronet Sign MOU for Up to 5 Million
Tonnes of LNG Through Equity Investment in
Driftwood
Pickering Energy Partners, Henry Resources Strike
Permian Basin JV Deal
Callon Highlights Compelling Value Proposition of
Transaction with Carrizo
TPG Terminates $930 Million Purchase of Shale
Water Handler Goodnight Midstream
Talos Energy Announces Full Year 2019 Operating
and Financial Guidance (includes A&D
announcement)
BMO Deals (Status)
Siltstone Appalachia (In Market) – See page 4
PayRock Eagle Ford (In Market) – See page 5
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4
September 30, 2019
Opportunity to acquire a substantial portfolio of mineral and
royalty assets in the core of the Utica, Marcellus, and Upper
Devonian
52,406 net royalty acres(1), 1,771 ORRI acres(1), and
1,930 additional leased working interest acres
Low concentration risk, with interest in >625 currently
producing wells across 20 counties in OH, PA, and WV
March 2019 production of 16.2 net mmcfe/d (90% gas)
with drilling inventory consisting of >5,000 locations
Well-distributed acreage provides high-confidence upside
exposure across the tri-state region
Siltstone has exposure to >50% of the future
development locations in core Utica
Source: Siltstone 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 soon
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
Virginia
Butler
Indiana
Somerset
Stark
Randolph
Fayette
Garrett
Hardy
Grant
Preston
Clarion
Wayne
Mercer
Greene
Cambria
Allegheny
Washington
Meigs
Roane
Athens
Westmoreland
Lorain
Jefferson
Elk
PerryNoble
Pendleton
Lewis
Braxton
Ritchie
Belmont
Mason
Wood
Armstrong
Portage
Clearfield
Tucker
Beaver
Carroll
Monroe
Trumbull
Muskingum
Gallia
Wirt
Medina
Jackson
Bedford
Holmes
Morgan
Summit
Washington
Guernsey
Tyler
Coshocton
Wetzel
Gilmer
Harrison
Upshur
Harrison
Tuscarawas
Rockingham
Ashland
Marion
Jefferson
Columbiana
Mineral
Mahoning
Barbour
Knox
Venango
Webster
Lawrence
Marshall
Hampshire
Allegany
Clay
Calhoun
Monongalia
Doddridge
Licking
Taylor
Putnam
Cuyahoga
Ohio
Pocahontas
Shenandoah
Kanawha
Vinton
Geauga
Pleasants
Hocking
Brooke
Blair
CabellHighland
Nicholas
Forest
Legend
Hancock
Austin Chalk Wells Since 2015Sized by Peak IP30 boe/d
Siltstone Footprint
Drilling Rigs
PENNSYLVANIA
WEST VIRGINIA
OHIO
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
Elk
Erie
Tioga
Potter
Steuben
Centre
Berks
Bradford
Lycoming
Clinton
McKean
Clearfield
Allegany
Luzerne
Cattaraugus
Blair
Wayne
Perry
Tioga
Broome
Ontario
Chenango
Schuylkill
Cayuga
Madison
Otsego
Monroe
Onondaga
Mifflin
Indiana
Cambria
Yates
Wayne
Monroe
WyomingLivingston
Susquehanna
Cortland
Dauphin
Sullivan
Jefferson
Genesee
Delaware
Juniata
Union
Carbon
Huntingdon
Columbia
Tompkins
Niagara
Lehigh
Seneca
Oneida
Snyder
Wyoming
Cameron
Chemung
Lebanon
Schuyler
Lackawanna
Northumberland
Orleans
Warren
Pike
Herkimer
Montgomery
Northampton
Bucks
Montour
Forest
Lancaster
Erie
Chester
PENNSYLVANIA
6
Acreage concentrated in the core of the play
Exposure to premier acreage within portfolios of 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 midstream de-bottlenecking efforts
Substantial free cash flow generation
Royalty revenue from interest in >625 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 >175 DUCs/PUDs
Wells spud on Siltstone acreage increasing annually
Comprehensive land and title documentation (both digital and hard copy)
OH29,173 PA
13,785
WV9,448
Net Royalty Acres
by State(1)
52% in
Belmont and
Jefferson, OH
42% in
Washington and
Greene, PA
OH86%
PA9%
WV5%
Production
by State(2)
Production
by Formation(2)
Utica87%
Marcellus13%
Concentrated in most
economic and actively
developed areas
Production
by Operator(2)
EQT23%
Encino22%
GPOR21%
Ascent12%
AR7%
MR4%
CNX3% SWN
2%
Other6%
5
September 30, 2019
Opportunity to acquire economic, highly contiguous,
and de-risked acreage position in the Eagle Ford
11,212 gross / net largely undeveloped acres located
in La Salle, McMullen, and Dimmit counties, TX
100% operated with 100% working interest
Highly economic locations with average >8,500’
lateral length and robust EURs of >100 boe/ft
Executable optimized development plan on 660’
well spacing supports 63 gross drilling locations
in the Lower Eagle Ford
Volatile oil window provides favorable liquids content
with pressure and gas volumes to sustain solution gas
drive
June 2019 net production of ~1,500 boe/d (72%
liquids) from 4 gross wells
Offset activity by top tier operators including EOG,
Chesapeake, XTO, Sundance Energy, EP Energy,
and Carrizo
Significant upside potential from Upper Eagle Ford
and Austin Chalk
EOR pilots being delineated near PayRock’s acreage
position
Favorable marketing contracts and no minimum
volume commitments or acreage dedications
VDR available now
Contact Chelsea Neville at [email protected] or
713-546-9703 for a Confidentiality Agreement and access to the VDR
Source: PayRock Energy 2019 Eagle Ford Divestiture announcement
Asset Ready for
Full-Scale
Development
High degree of control as asset is 100% operated
Nominal number of leases simplifies the management of the land position
Ample access to third party gathering for oil and gas in addition to salt water disposal
No minimum volume commitments or acreage dedications
Largely
Undeveloped
Blocky Eagle Ford
Position
Attractive acquisition opportunity with exposure to the highly economic Eagle Ford volatile oil window
11,212 net acre position located in La Salle, McMullen, and Dimmit counties, TX
100% operational control with 100% working interest and 75% NRI across acreage
Distinct contiguous acreage blocks allow for average lateral length >8,500’ and 23 locations in excess of 10,000’
High Quality
Subsurface
Attributes
The Lower Eagle Ford exhibits exceptional reservoir quality across PayRock’s acreage
Efficiently developed with a single drilling target
Average in-place volume of 15 MMBO/section
Two distinct Eagle Ford reservoirs allow for flexible development strategy
Shallow, liquids-rich, low water saturation in the Thurman area
Deeper, volatile oil with significant over-pressure in the STS area
The Austin Chalk represents significant opportunity for co-development with the Eagle Ford
Thurman overlies a thick section of reservoir-quality lower Austin Chalk
Sugarkane Field has demonstrated that higher GORs support success in the Austin Chalk
Highly Economic
Drilling Inventory
through
Enhanced
Completions
One of the last remaining undeveloped areas of scale in the core Eagle Ford
63 gross operated Lower Eagle Ford drilling locations at conservative 660’ inter-well spacing provide ample running room
Position de-risked by existing wells and offset performance
PayRock wells exceed historical type curve for the area due to improved completion technology
Additional upside from offsetting Austin Chalk activity, a potential second bench in the Eagle Ford, and EOR pilots in the
area
Currently on the Market from BMO: PayRock Energy Eagle Ford Divestiture
ASSET HIGHLIGHTS
ASSET OVERVIEW PROCESS OVERVIEW
.
ASSET MAP
6
September 30, 2019
Historical Prices as of 26-Sep-19 Close ($/gal)
NGLs Current Last Wk. 6 Mo. Ago 1 Yr. Ago
Ethane $0.19 $0.21 $0.23 $0.50
Propane $0.47 $0.46 $0.64 $1.05
Butane $0.55 $0.56 $0.62 $1.21
Iso-butane $0.84 $0.71 $0.83 $1.27
Pentane+ $1.15 $1.14 $1.28 $1.60
NYMEX Gas Futures as of 26-Sep-19 Close ($/mmbtu)
Period(1) Current Last Wk. 6 Mo. Ago 1 Yr. Ago
12 Mo. Strip $2.46 $2.53 $2.92 $2.84
2019 $2.49 $2.61 $2.87 $2.77
2020 $2.47 $2.51 $2.76 $2.64
2021 $2.46 $2.46 $2.66 $2.60
2022 $2.64 $2.63 $2.83 $2.73
2023 $2.64 $2.63 $2.83 $2.73
NYMEX WTI Futures as of 26-Sep-19 Close ($/bbl) NYMEX Gas Futures as of 26-Sep-19 Close ($/mmbtu)
Period(1) Current Last Wk. 6 Mo. Ago 1 Yr. Ago
12 Mo. Strip $54.32 $56.07 $60.00 $70.23
2019 $56.35 $58.08 $60.21 $69.98
2020 $53.60 $54.80 $58.69 $66.17
2021 $51.37 $51.81 $56.28 $62.64
2022 $51.05 $51.04 $54.56 $59.87
2023 $51.43 $51.17 $53.76 $58.08
25%
35%
45%
55%
65%
Feb-16 Aug-16 Feb-17 Aug-17 Feb-18 Aug-18 Feb-19 Aug-19
% o
f W
TI
NGL as % of WTI
$1
$2
$3
$4
$5
Sep-18 Mar-19 Sep-19 Mar-20 Sep-20
($/m
mb
tu)
$20
$30
$40
$50
$60
$70
$80
Sep-18 Mar-19 Sep-19 Mar-20 Sep-20
($/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 19-Sep-19 Close ($/gal)
NGLs Current Last Wk. 6 Mo. Ago 1 Yr. Ago
Ethane $0.21 $0.23 $0.27 $0.59
Propane $0.46 $0.43 $0.68 $1.06
Butane $0.56 $0.49 $0.68 $1.18
Iso-butane $0.71 $0.63 $0.86 $1.35
Pentane+ $1.14 $1.03 $1.30 $1.57
NYMEX Gas Futures as of 19-Sep-19 Close ($/mmbtu)
Period(1) Current Last Wk. 6 Mo. Ago 1 Yr. Ago
12 Mo. Strip $2.53 $2.56 $3.01 $2.78
2019 $2.61 $2.65 $2.97 $2.73
2020 $2.51 $2.54 $2.78 $2.62
2021 $2.46 $2.47 $2.66 $2.58
2022 $2.63 $2.63 $2.84 $2.72
2023 $2.63 $2.63 $2.84 $2.72
NYMEX WTI Futures as of 19-Sep-19 Close ($/bbl) NYMEX Gas Futures as of 19-Sep-19 Close ($/mmbtu)
Period(1) Current Last Wk. 6 Mo. Ago 1 Yr. Ago
12 Mo. Strip $56.07 $53.82 $59.88 $69.34
2019 $58.08 $55.00 $59.89 $68.78
2020 $54.80 $53.10 $58.99 $65.07
2021 $51.81 $51.29 $56.95 $61.74
2022 $51.04 $50.82 $55.44 $59.23
2023 $51.17 $51.08 $54.73 $57.60
7
September 30, 2019
($0.32)
AECO
Northern
California
Sumas
Southern
California
El Paso - SJ
Waha
HSC
Henry Hub
Panhandle
CIG Chicago
Dominion
Transco
$2.32
($0.11)
$2.55
$0.12
$3.09
$0.66
$1.63
($0.80)
$2.35
($0.08)
$1.28
($1.15)
$2.43
$1.63
($0.80)
$1.35
($1.08)
$1.80
($0.63)
$1.73
($0.70)
$2.10
($0.33)
$1.73
($0.70)
Clearbrook
Midland
Cushing
St. James
(LLS)
East Coast
U.S. (Brent)
Midland Sweet-
Sour Spread
EMS
$53.91
($2.50)
$62.74
$6.33
$56.41
NATURAL GAS PRICING & DIFFERENTIALS TO HENRY HUB ($ / MMBTU) – AS OF 26-SEP-19
Commodity Prices (cont’d)
OIL PRICING & DIFFERENTIALS TO CUSHING WTI ($ / BBL) – AS OF 26-SEP-19
$50.66
($5.75)
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
TBU
TBU
TBU
TBU
TBU
TBU
TBU
TBU $58.98
$2.57
$57.08
$0.67
TBU
TBU
TBU
8
September 30, 2019
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
Item Value Wkly Change Last Week Item Value Wkly Change Last Week
Rig Count 414 (3) 417 Oil Differential $0.85 $0.55 $0.30
Permitting Activity 86 (43) 129 Gas Differential ($0.81) ($0.05) ($0.76)
-$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
4,057
13,900
9931,212
1,010868
1,247
1,0651,207
1,050
1,256
910763 744
417
Sep-18 Nov-18 Jan-19 Mar-19 May-19 Jul-19 Sep-19
H V+D
--
$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
1 2 8 8 6 6 12 13 15 7 2 2 7 2 5 4 1 2 0
$ /
acre
# Deals
$25,221
Ann'd
Date Buyer Seller Asset Description Value(1)
Proved
Multiple
Prod.
Multiple Net Acres
($mm) ($/boe) ($/boe/d) ($/acre)(2)
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
30-Jul-19 Viper Energy Partners Diamondback Energy Permian royalty assets $700 n.a. $175,000 nmf
Mean $668 n.a. $106,381 $21,591
Median $700 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
--
$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
1 2 6 9 5 7 11 9 9 6 1 0 7 2 5 4 1 2 3
$ /
bo
e/d
# Deals
$113,122
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
9
September 30, 2019
0%
5%
10%
15%
20%
--
100
200
300
Jan-15 Jan-16 Jan-17 Jan-18 Jan-19
H V+D % of Total Rigs
Item Value Wkly Change Last Week Item Value Wkly Change Last Week
Rig Count 75 (2) 77 Oil Differential $2.95 ($0.70) $3.65
Permitting Activity 30 (21) 51 Gas Differential ($0.08) ($0.00) ($0.07)
-$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
1,353
6,916329
402350
315
398353
472
351
401
222175 200
161
Sep-18 Nov-18 Jan-19 Mar-19 May-19 Jul-19 Sep-19
H V+D
--$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
0 1 2 1 2 2 0 4 2 3 1 2 4 2 1 3 0 0 0
$ /
acre
# Deals
$6,130
--
$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
1 1 3 1 2 2 2 4 4 3 1 2 7 2 0 3 0 0 1
$ /
bo
e/d
# Deals
$68,384
Ann'd
Date Buyer Seller Asset Description Value(1)
Proved
Multiple
Prod.
Multiple Net Acres
($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
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
10
September 30, 2019
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
Item Value Wkly Change Last Week Item Value Wkly Change Last Week
Rig Count 54 -- 54 Oil Differential $3.60 -- $3.60
Permitting Activity 6 (18) 24 Gas Differential -- -- --
--
$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
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
81
11,502177 180
115 105
174
113 116 116132
8698
177
70
Sep-18 Nov-18 Jan-19 Mar-19 May-19 Jul-19 Sep-19
H V+D
--$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
0 0 5 1 1 3 2 3 0 2 2 0 1 1 2 1 0 1 1
$ /
mcfe
/d
# Deals
$4,808
--
$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
0 0 3 1 1 2 1 3 0 1 2 0 1 1 1 1 0 1 1
$ /
acre
# Deals
$3,267
Ann'd
Date Buyer Seller Asset Description Value(1)
Proved
Multiple
Prod.
Multiple Net Acres
($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
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
11
September 30, 2019
0%
5%
10%
15%
20%
--
50
100
150
Jan-15 Jan-16 Jan-17 Jan-18 Jan-19
H V+D % of Total Rigs
Item Value Wkly Change Last Week Item Value Wkly Change Last Week
Rig Count 63 -- 63 Oil Differential $6.33 $0.06 $6.27
Permitting Activity 13 (43) 56 Gas Differential ($1.12) ($0.33) ($0.79)
-$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
101
30,257
373 370
305258
397
276
382419
384334 346
278
176
Sep-18 Nov-18 Jan-19 Mar-19 May-19 Jul-19 Sep-19
H V+D
--$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
0 1 0 0 1 2 2 3 2 5 1 4 3 4 3 1 1 0 2
$ /
mcfe
/d
# Deals
$4,878
--$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
0 1 0 0 1 2 2 4 2 4 1 3 1 3 2 0 0 0 0
$ /
acre
# Deals
$2,083
Ann'd
Date Buyer Seller Asset Description Value(1)
Proved
Multiple
Prod.
Multiple Net Acres
($mm) ($/mcfe) ($/mcfe/d) ($/acre)(2)
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.
15-Oct-18 Undisclosed Buyer Range Resources Corp Overriding royalty interests in Appalachia $300 n.a. $17,649 nmf
Mean $277 $0.32 $9,359 $2,814
Median $300 $0.32 $9,509 $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
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
12
September 30, 2019
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
Item Value Wkly Change Last Week Item Value Wkly Change Last Week
Rig Count 53 -- 53 Oil Differential ($2.50) ($0.50) ($2.00)
Permitting Activity 18 (28) 46 Gas Differential ($0.72) -- ($0.72)
-$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
1,432
2,918
127
201
12896
133
114
144 138 145 144 154137
87
Sep-18 Nov-18 Jan-19 Mar-19 May-19 Jul-19 Sep-19
H V+D
--
$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
0 0 1 2 0 0 2 3 1 0 3 2 0 5 2 0 0 1 0
$ /
acre
# Deals
$2,702
--
$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
0 1 1 4 0 2 3 3 0 1 3 3 0 6 3 0 0 1 0
$ /
bo
e/d
# Deals
$43,737
Ann'd
Date Buyer Seller Asset Description Value(1)
Proved
Multiple
Prod.
Multiple Net Acres
($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
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
13
September 30, 2019
0%
5%
10%
15%
20%
--
50
100
150
Jan-15 Jan-16 Jan-17 Jan-18 Jan-19
H V+D % of Total Rigs
Item Value Wkly Change Last Week Item Value Wkly Change Last Week
Rig Count 65 (2) 67 Oil Differential ($2.50) ($0.50) ($2.00)
Permitting Activity 26 (72) 98 Gas Differential ($0.72) -- ($0.72)
-$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
12,500
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 Gas
874
13,718
512
689
829 812
352 402 494
328164
306 283
434
228
Sep-18 Nov-18 Jan-19 Mar-19 May-19 Jul-19 Sep-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
--$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
2 0 4 4 1 6 2 0 1 6 3 9 3 1 3 1 1 0 2
$ /
bo
e/d
# Deals
$36,959
--
$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
0 0 3 3 0 1 1 0 1 0 1 5 2 0 2 1 0 0 0
$ /
acre
# Deals
$4,655
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
TBU
TBU
TBU TBU
TBU
TBU
TBU
TBU
TBU
TBU TBU
14
September 30, 2019
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
Item Value Wkly Change Last Week Item Value Wkly Change Last Week
Rig Count 72 -- 72 Oil Differential -- -- --
Permitting Activity 42 (58) 100 Gas Differential ($0.80) ($0.06) ($0.75)
-$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 763
14,274
449405 382
355403
339
435
389298
359 341311
259
Sep-18 Nov-18 Jan-19 Mar-19 May-19 Jul-19 Sep-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)
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
12-Jun-19 Glendale Energy; TPG Undisclosed Seller Non-op interests in STACK $55 n.a. n.a. n.a.
Mean $124 $2.30 $15,435 $539
Median $80 $2.30 $16,429 $295
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
1 3 1 2 0 3 3 2 4 1 2 1 0 0 0 1 0 0 0
$ /
acre
# Deals
$5,760
--
$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
1 4 1 3 1 6 3 1 4 2 4 5 2 2 5 4 2 0 3
$ /
bo
e/d
# Deals
$40,951
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
15
September 30, 2019
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
Item Value Wkly Change Last Week Item Value Wkly Change Last Week
Rig Count 22 (1) 23 Oil Differential $3.60 -- $3.60
Permitting Activity 14 5 9 Gas Differential -- -- --
--
$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 Gas1,932
3,116
3339
32 30 32 33
2629
26 27 28
22
36
Sep-18 Nov-18 Jan-19 Mar-19 May-19 Jul-19 Sep-19
--
$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
0 0 1 1 0 0 2 0 0 0 0 1 2 2 2 1 1 3 0
$ /
bo
e/d
# Deals
$32,727
--
$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
0 0 1 0 0 0 2 1 0 0 0 1 2 1 0 1 1 2 0
$ /
bo
e
# Deals
$16.39
Ann'd
Date Buyer Seller Asset Description Value(2)
Proved
Multiple
Prod.
Multiple Net Acres
($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
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
16
September 30, 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
September 2019 Sep 30-Oct 2 SPE Annual Technical Conference and Exhibition
October 2019 Oct 9 IPAA Leaders in Industry Luncheon
Oct 15 Houston Producers Forum Luncheon
Oct 18 ADAM-Houston Monthly Luncheon
Oct 22-23 A&D Strategies and Opportunities Conference
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 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 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
17
September 30, 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.
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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
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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
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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
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.
414
(3)
53
--
12
--
51
--22
(1)
22
(1)
5
(1)55
1
54
--
75
(2)
16
--
3
--
25
--12
(1)
This
Week Change
Last
Week
Last
Year
Total Rigs 860 (8) 868 1,054
Oil 713 (6) 719 863
Gas 146 (2) 148 189
Miscellaneous 1 -- 1 2
Directional 57 (4) 61 69
Horizontal 752 (4) 756 922
Vertical 51 -- 51 63
Basin
Permian 414 (3) 417 486
SCOOP/STACK/Merge 55 1 54 110
Granite Wash 5 (1) 6 27
Eagle Ford 75 (2) 77 92
Haynesville 54 -- 54 56
Marcellus 51 -- 51 55
Utica 12 -- 12 20
Williston 53 -- 53 53
DJ-Niobrara 22 (1) 23 28
Green River 12 (1) 13 18
Powder River 25 -- 25 15
Piceance 3 -- 3 7
Gulf Coast Onshore 16 -- 16 27
GOM 22 (1) 23 18
Alaska 8 -- 8 6
Other 33 -- 33 36
Mid-Con 12 -- 12 18
Rockies 3 -- 3 3
Western 16 -- 16 13
Eastern 2 -- 2 2
Michelle Tankimovich
Analyst
TBU
TBU
TBU
TBU