february 2020 in review - ad library · 2-oct-17 franco-nevadaosum oil sands (royalty assets) $93...
TRANSCRIPT
March 05-2020
Updated to market close on Current Previous Month Monthly ChangeMarch 4th, 2020 Value Value Percent DirectionEdmonton Mixed Sweet (C$/bbl)(2) $59.17 $62.47 (5.3%)
Western Canadian Select (C$/bbl)(2) $43.62 $42.55 2.5%
AECO (C$/GJ)(2) $1.65 $1.67 (1.2%)
US$/C$(2) $0.7458 $0.7531 (1.0%)
Monthly A&D Transaction Value ($MM)(1)(3) $24.0 $77.0 (68.8%)
Monthly A&D Transaction Count(1) 1 1 -- --Canadian Rig Count 206 256 (19.5%)
Canadian Oil/Cond Production (MMbbl/d)* 2.9 2.8 2.2%
Canadian Gas Production (Bcf/d)* 19.2152 19.0 1.2%
Canadian Gas Storage (Bcf) 364.0 527.6 (31.0%)
$2.6
$8.0
$5.9
$2.2
$1.1
$2.1
$0.2
$3.7 $4.5
$1.4
$8.0 $8.3
$0.6
$2.1 $2.2 $3.4
$6.5 $6.2
$2.3 $3.6
$1.6
$6.7
$0.9
$4.0
$0.6
$3.2 $3.0 $3.5
$0.8 $1.7
$3.8
$2.6
$0.6
$4.0
$1.4 $1.0 $0.0 $0.2 $0.2 $0.2 $0.1
$0$1$2$3$4$5$6$7$8$9
Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1
2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020
$18.7 $7.1 $22.2 $8.4 $18.6 $13.1 $10.4 $9.0 $7.0 $0.7 $0.1
Tran
sact
ion
Valu
e (C
$B)
Asset Corp PrivateCo Average
Tourmaline Oil Corp’s acquisition of Chinook Energy for C$24MM
1
February 2020 in Review HIGHLIGHTS IN THIS ISSUE:
The crude oil markets saw another month of volatility due to concerns as COVID-19 spreads globally. Crude oil peaked at ~$54/bbl and closed the month just below $45/bbl, while NYMEX gas market reached the lowest February settlement in 20 years as a result of a warmer winter season (Pages 2, 5)
Check out our special page on the North Montney Mainline and the increased access to additional markets (Page 8)
WCSB active weekly rig count at 206 - down over last year’s levels by 6% (Page 9)
Key Industry Indicators
Quarterly Deal Activity (Producing Assets Only)(3) 1 deal
announced in February
Source: BMO Capital Markets, *All production throughout this document is sourced from geoSCOUT, only includes BC/AB/SK/MB and does not include oil sands mining. Production volumes are raw. 1. Deals larger than C$20MM; transactions are reported based on announcement/disclosure dates. 2. Current prices as of March 4th, 2020 close. Previous month prices as of February 5th, 2020 close. 3. Chart excludes joint ventures, oil sands transactions, and notable transactions including: CNOOC-Nexen (C$17.9B); Repsol-Talisman (C$15.9B); CNRL-Shell (C$12.6B); Cenovus-ConocoPhillips
(C$17.7B); Pengrowth’s disposition announced on October 18, 2017; Aspenleaf-NEP (announced on August 31, 2018); Pacific Oil-Canbriam (announced on May 13, 2019); CNRL-Devon C$3.78B (announced May 29, 2019); Cona-Pengrowth C$740MM announced Nov 1, 2019.
DEALS ANNOUNCED IN FEBRUARY(1):
March 05-2020
2
February was a challenging month for oil prices as COVID-19 became a global problem; impacting transportation networks, industrial operations and consumer activity. Global growth and oil demand were revised down. Prompt WTI opened February at $50, peaked just under $54 on the 20th and closed the month below US$45/bbl (~-17%); the biggest one week drop since 2008
Early optimism that OPEC+ Joint Technical Committee would act swiftly as they met in the first week of February. It appeared that the Saudis were pushing for a cut, but Russia was opposed (as their national budget is less reliant on oil prices), in the end the group decided not to act, waiting instead for their planned meeting on March 5/6
February saw Enbridge’s Line 3 replacement and expansion project clearing important regulatory hurdles in Minnesota, this expansion would add around 370 Mbbl/d of additional capacity out of Canada
Another derailment near Guernsey, Saskatchewan occurred in February. This is the second train derailment in the same area since December 9th which caused the federal government to order trains that carry crude to slow down to 32 km/h in metropolitan areas and to 40 km/h outside of metropolitan areas
WCS tightened over the month closing at $-13.65. Canadian grade strength was driven by declining Alberta inventories and we also saw the U.S. place sanctions on Rosneft and their trading subsidiaries due to their continued dealing with the sanctioned regime of Venezuela. We are watching this closely as it could mean the Gulf will be short heavy barrels once in effect
Equity Markets The Canadian new issue market raised gross proceeds of
approximately C$3.2B in February with no transactions in the energy or PE&I space
2020 YTD, energy High Yield has accounted for 12.6% of all new issue deal and 12.2% of new dollar volume, up significantly from 2019; E&P has accounted for ~39% of energy deals and midstream ~28%, a sharp reversal from 2019
The High Yield primary saw no activity this past week as investors remain on the sidelines amidst COVID-19 fears
The Leveraged Loan market had a tentative tone this week due to concerns around COVID-19, causing arrangers to flex transactions and pull some deals altogether; excluding repricings,16 issuers allocated 18 tranches to raise $6.5B this week
On Feb. 19, Tallgrass Energy priced $430 million of 6.00% Senior Notes due 2027 at $98.591 to yield 6.250%
On Feb. 11, Buckeye Partners priced $500 million of 4.125% Senior Notes due 2025 and $500 million of 4.50% Senior Notes due 2028 at par
The U.S. HY Energy Index widened ~226 bps and the broader U.S. HY Index widened ~72 bps in February
Commodities
Debt Markets
Source: BMO Capital Markets
CRUDE
NATURAL GAS
NATURAL GAS CONTINUED
NYMEX: February saw a continuation of January, U.S. natural
gas persisted with its slide as the absence of cold weather across Europe and North America prevented any meaningful drawdown on inventories. Lower 48 inventories sit at a healthy 2,343 Bcf which marks a 780 Bcf departure from this time last year. Conversely, European gas inventories sit at 2,400 Bcf which is about 800 Bcf higher than this time last year. The reason behind such high inventory is partly due to increasing Lower 48 natural gas production (currently sitting at 92.5 Bcf/d), but mainly the absence of cold weather in key markets. Europe saw it’s warmest January ever, while the U.S. notched its fifth warmest January since records began
AECO: In Alberta the biggest development in natural gas markets for February was NGTL bringing on the highly anticipated North Montney Mainline expansion. Phase one of the project, which is slated to bring an additional 672 MMcf/d of supply to NGTL began flowing on February 1st, while Phase two will bring an additional 813 MMcf/d onto the system in April 2020. While the full capacity of Phase one is yet to be realized, our estimates point to 300-400 MMcf/d of new production coming online. The rig count corroborates this supply increase as producers have but 12 rigs to work in the area surrounding the North Montney Mainline
March 05-2020
Parameters Metrics
Prod. % Gas P+P Production P+P
(C$ MM) (boe/d) (%) (Mboe) (EV$/boe/d) (EV$/boe)
24-Feb-20 Tourmaline Chinook Energy $24 3,500 86% 35,600 $6,971 $0.69 Northeast BC20-Jan-20 IPC Granite $77 1,515 0% 14,000 $50,937 $5.51 S. Eastern AB5-Dec-19 Bonavista Paramount (West Central AB Assets) $53 8,200 56% 47,432 $6,500 $1.12 Central AB6-Nov-19 Tourmaline Undisclosed (Peace River High Assets) $175 5,600 50% 62,000 $31,250 $2.82 Grande Prairie1-Nov-19 Cona Pengrowth $740 22,708 19% 446,508 $32,588 $1.66 Ath/Cold Lake18-Oct-19 Tourmaline Painted Pony (NE BC Montney Assets) $45 -- n.a. n.a. n.a. n.a. Northeast BC3-Sep-19 Undisclosed Crescent Point (SE SK Assets) $212 7,000 15% 49,200 $30,286 $4.31 Area IV28-Jun-19 Freehold Surge (AB and SK Royalty Assets) $29 214 6% n.a. $136,290 n.a. Other26-Jun-19 Pieridae Energy Shell Canada (Alberta Foothills Assets) $190 28,623 69% 119,957 $6,638 $1.58 Foothills29-May-19 CNRL Devon Canada $3,775 122,800 0% 879,000 $30,741 $4.29 Fort McMurray
Average / Total (Ex. Royalty) 9 Transactions (4 Oil, 5 Gas) $5,292 199,945 37% 1,653,697 $24,489 $2.75Oil Weighted $4,804 154,022 8% 1,388,708 $36,138 $3.94Gas Weighted $488 45,923 65% 264,989 $12,840 $1.55
WCSB RegionAnn'd Date Buyer Seller Enterprise
Value
Parameters Metrics
Ann'd Date Buyer Seller Enterpise Value Prod. % Gas Production Commentary
(C$ MM) (boe/d) (%) (EV$/boe/d)28-Jun-19 Freehold Surge (AB and SK Royalty Assets) $29 214 6% $136,290 Gross overriding royalty on central & northern AB, SW SK assets28-Feb-18 Freehold Cardinal (Various Royalties) $24 110 n.a. $218,182 Gross overriding royalty on the Mitsue Gilwood Unit27-Feb-18 PrairieSky Undisclosed (AB Viking Royalty Assets) $46 300 54% $153,333 Producing gross overriding royalty acquired27-Feb-18 PrairieSky Undisclosed (Clearwater Royalty Assets) $33 n.a. 0% n.a. Non-producing gross overriding royalty acquired30-Jan-18 Burgess Connacher (Royalty Assets) $44 n.a. 0% n.a. Sliding scale royalty on all lands containing bitumen20-Dec-17 Freehold Bonterra (Pembina GORR) $52 210 26% $247,619 2% gross overriding royalty on its Pembina Cardium pool10-Nov-17 Undisclosed Obsidian (Eastern Alberta Royalty) $40 181 38% $220,994 Royalty interest in Eastern Alberta2-Oct-17 Franco-Nevada Osum Oil Sands (Royalty Assets) $93 310 0% $298,387 4% gross overriding royalty interest on its Orion Project2-Mar-17 Freehold Undisclosed (Royalty Assets) $34 185 9% $183,784 32,000 acres in the Dodsland Viking9-Feb-17 Burgess Athabasca (Royalty Assets) $90 -- 0% n.a. Upsized: Includes Leismer and Corner lease16-Dec-16 Undisclosed Cavalier (Royalty Assets) $100 -- n.a. n.a. Sliding scale (0-20%) starting at US$50/bbl WCS14-Dec-16 PrairieSky Pengrowth (Royalty Assets) $250 608 0% $411,455 4% royalty on Lindbergh properties, including future development14-Dec-16 Burgess Athabasca (Royalty Assets) $50 -- 0% n.a. Upsized: Modified sliding scale and starting point1-Dec-16 PrairieSky BlackPearl / Other (Royalty Assets) $117 460 17% $255,000 Acquired a combined 3.95% royalty interest at Onion Lake3-Nov-16 Burgess Athabasca (Royalty Assets) $129 n.a. 0% n.a. Upsized: Sliding scale (0-12%) starting at US$75/bbl WTI27-Jun-16 PrairieSky Pine Cliff (Royalty Assets) $25 n.a. n.a. n.a. 99,930 net fee title acres20-Jun-16 Burgess Athabasca (Royalty Assets) $129 -- 0% n.a. Sliding scale (0-6%) starting at US$75/bbl WTI2-May-16 Freehold Husky (Royalty Assets) $165 1,700 70% $97,059 Acquired >2MM net acres across Western Canada
Average / Total 18 Transactions $1,449 4,278 15% $222,210
3
The 10 Most Recent Transactions Over $20 Million(1)
Oil Sands Transactions (2016 – Present)
Royalty Transactions (2016 – Present)
Note: Transactions that occurred after the month being covered in this report are not included Source: BMO Transaction Database Denotes current month transaction Blue = BMO Capital Markets provided transaction advisory services Green = BMO Capital Markets provided acquisition financing or related services
1. Excludes Pacific Oil’s acquisition of Canbriam announced on May 13, 2019 (no transaction value disclosed) and Karve’s acquisition of High Ground (no transaction value disclosed).
2. CNRL also acquired Devon’s Bonnyville heavy oil assets (20,100 bbl/d) as part of the transaction.
(2)
Parameters Metrics Date Acquiror Target Type EV Prod. % Gas P+P EV / Prod. EV / P+P
(C$MM) (boe/d) (%) (Mboe) (C$/boe/d) (C$/boe)
1-Nov-19 Cona Pengrowth SAGD $740 22,708 19% 446,508 $32,588 $1.6629-May-19 CNRL Devon Canada SAGD $3,775 122,800 -- 879,000 $30,741 $4.2910-Oct-18 IPC BlackPearl SAGD $712 11,250 1% 162,434 $63,310 $4.3831-Aug-18 CNRL Joslyn Oil Sands Project Mining $225 n.a. n.a. n.a. n.a. n.a.26-Jul-18 CNRL Laricina SAGD $67 n.a. n.a. 389,000 n.a. $0.1712-Feb-18 Suncor Mocal Energy (5% Syncrude W.I.) Mining $921 16,226 -- 122,441 $56,749 $7.523-Jan-18 Suncor Total E&P Canada (3.31% Fort Hills W.I.) Mining $453 6,545 -- 94,804 $69,211 $4.783-Jan-18 Teck Total E&P Canada (1.30% Fort Hills W.I.) Mining $179 2,571 -- 37,234 $69,633 $4.8129-Mar-17 Cenovus ConocoPhillips (FCCL and Deep Basin Assets) SAGD $17,730 284,396 31% 3,965,833 $62,341 $4.479-Mar-17 CNRL Shell & Marathon (70% AOSP W.I.) Mining $12,592 201,800 -- n.a. $62,397 n.a.9-Mar-17 Shell Marathon (10% AOSP W.I.) Mining $1,683 26,857 -- n.a. $62,660 n.a.Average / Total 11 Transactions $39,076 695,153 6% 6,097,254 $56,626 $4.01Median $740 22,708 -- 275,717 $62,397 $4.43
March 05-2020
$0.2B27%
$0.2B23%
$0.2B29%
$0.2B22%
0% 20% 40% 60% 80% 100%
41% 59%
0% 20% 40% 60% 80% 100%
$0.5B62%
$0.2B25%
0% 20% 40% 60% 80% 100%
$3.8B84%
$0.7B16%
0% 20% 40% 60% 80% 100%
$0.7B16%
$3.8B84%
0% 20% 40% 60% 80% 100%
97%
0% 20% 40% 60% 80% 100%
4 Source: BMO Transaction Database 1. Deals larger than C$20MM; transactions are reported based on announcement/disclosure
dates. 2. Chart excludes joint ventures, oil sands transactions, and notable transactions including:
Cenovus-ConocoPhillips (C$17.7B); Pengrowth’s disposition announced on October 18,
2017; Aspenleaf-NEP (announced on August 31, 2018); Pacific Oil-Canbriam (announced on May 13, 2019); CNRL-Devon C$3.78B (announced May 29, 2019); Cona C$740MM (announced November 2019).
3. Excludes royalty transactions.
LTM Transaction Breakdown (By Deal Value) SELLER BUYER OIL VS. GAS
Yield Junior / Interm.
PrivateCo/Sponsor Undisclosed Senior
Foreign Other Gas Oil
E&P(1
)(2)
O
il Sa
nds(2
)
~62% of value acquired by Junior / Interm. buyers
OIL-WEIGHTED TRANSACTIONS
GAS-WEIGHTED TRANSACTIONS
A&D Valuation Trends(1,2,3)
+/- 1 Standard Deviation Annual Weighted Average MSW (Right-hand axis) Average Multiple
+/- 1 Standard Deviation Annual Weighted Average AECO (Right-hand axis) Average Multiple
$20
$40
$60
$80
$100
$120
--
$20,000
$40,000
$60,000
$80,000
$100,000
$120,000
$140,000
Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1
2015 2016 2017 2018 2019 2020
MSW
(C$/bbl)
EV/P
rodu
ctio
n ($
/boe
/d)
--
$2
$4
$6
$8
$10
--
$20,000
$40,000
$60,000
$80,000
$100,000
$120,000
$140,000
Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1
2015 2016 2017 2018 2019 2020
AEC
O (C
$/MM
BTU
)EV
/Pro
duct
ion
($/b
oe/d
)
~29% of value sold by Yield sellers
March 05-2020
Legend
US$/bbl C$/bbl US$/bbl Diff C$/bbl Diff
Cushing (37 - 42o)
MSW (39.5o)
Clearbrook (~ 40o)
Midland (~ 40o) St. James LLS (~ 40o)
East Coast U.S. Brent (38o)
WCS (20.5o)
Southern California
Henry Hub
Dominion
Dawn
Chicago Citygate
AECO Station 2
Northern California
Legend
US$/MMBTU C$/GJ US$/MMBTU C$/GJ Diff Diff
Transco
El Paso - SJ
Waha
Sumas
Maya (~ 22o)
Commodity Prices – March 4th, 2020
Source: BMO Commodity Products Group, Bloomberg – Prompt Pricing US$/C$ spot rate of 1.3408 used for all conversions from Bloomberg as of March 4, 2020. 5
NATURAL GAS PRICING & DIFFERENTIALS TO HENRY HUB (US$ / MMBTU | C$ / GJ)
OIL PRICING & DIFFERENTIALS TO CUSHING WTI (US$ / BBL) – OIL API GRAVITY IN PARENTHESIS
$46.78 $62.72
$49.79 $66.76
$3.01 $4.04
$51.13 $68.56
$4.35 $5.83
$46.63 $62.52
($0.15) ($0.20)
$48.10 $64.49
$1.32 $1.77
$44.13 $59.17
($2.65) ($3.55)$32.53 $43.62
($14.25) ($19.11)
$42.23 $56.62
($4.55) ($6.10)
$1.83 $2.32
$0.13 $0.16
($1.70) ($2.16)
($0.11) ($0.14)
($1.94) ($2.47)
$1.67 $2.12
($0.16) ($0.20)$1.50 $1.90
($0.33) ($0.42)
$1.41 $1.79
($0.42) ($0.53)
$2.69 $3.42
$0.86 $1.09
$1.59 $2.02
($0.24) ($0.31)
$1.30 $1.65
($0.53) ($0.67)
$1.72 $2.18
($0.11) ($0.14)
$1.23 $1.56
($0.60) ($0.76)
$1.40 $1.78
($0.43) ($0.55)
March 05-2020
$40
$50
$60
$70
$80
2020 2021 2022 2023
MSW
(C$/
bbl)
Strip 03/04/20 Evaluator AverageBMO Research
0
0.5
1
1.5
2
2.5
3
2012 2013 2014 2015 2016 2017 2018 2019 2020
Oil
Prod
uctio
n (M
Mbb
l/d)
SK AB BC MB
Source: geoSCOUT, BMO Capital Markets, Bloomberg Note: Evaluator Average Forecast - averaged Q4 2019 forecasts of GLJ, Sproule, McDaniel, and AJM Deloitte, BMO Research Average as of January 1, 2020.
1. Prices reported according to Bloomberg. 2. This page does not include oil sands mining or Northwest Territories well production. 6
0%
50%
100%
150%
200%
Dec-18 Mar-19 Jun-19 Sep-19 Dec-19 Mar-20
NGL
/ MSW
Spo
t
Edmonton Propane/MSW Edmonton Butane/MSWEdmonton Condensate/MSW
$0
$8
$16
$24
$32
$40
$48
$56
$10
$20
$30
$40
$50
$60
$70
$80
Dec-18 Mar-19 Jun-19 Sep-19 Dec-19 Mar-20
Diff
(US$
/bbl
)
WC
S (C
$/bb
l)
WTI - WCS Diff (US$/bbl) WCS
-$30
-$20
-$10
$0
$10
$20
$30
$40
$50
$60
$70
$80
$90
$100
Dec-18 Mar-19 Jun-19 Sep-19 Dec-19 Mar-20
Diff
(US$
/bbl
)
Edm
. C5
(C$/
bbl)
WTI - CND C5 Diff (US$/bbl) Canadian C5
$0
$6
$12
$18
$24
$30
$36
$42
$48
$20
$30
$40
$50
$60
$70
$80
$90
$100
Dec-18 Mar-19 Jun-19 Sep-19 Dec-19 Mar-20
Diff
(US$
/bbl
)
MSW
(C$/
bbl)
WTI - MSW Diff (US$/bbl) MSW
EDMONTON OIL PRICE FORECASTS
Oil/Liquids Fundamentals EDMONTON MIXED SWEET / WTI HISTORICAL CANADIAN CONDENSATE / WTI HISTORICAL
NGL AS A PERCENTAGE OF MSW(1) WESTERN CANADIAN SELECT / WTI HISTORICAL
WCSB OIL PRODUCTION(2)
March 05-2020
$1
$2
$3
$4
2020 2021 2022 2023
AEC
O (
C$/
MM
BTU)
Strip 03/04/20 Evaluator AverageBMO Research
0
100
200
300
400
500
600
Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec
Natu
ral G
as S
tora
ge (B
cf)
5-Year Range 5-Yr Avg2019 2020
0
500
1,000
1,500
2,000
2,500
3,000
3,500
4,000
4,500
Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec
5 Year Min/Max 5-Yr Avg2019 2020
Natu
ral G
as S
tora
ge (B
cf)
7
Natural Gas Fundamentals
Source: geoSCOUT, BMO Capital Markets, Bloomberg, NGX Note: Evaluator Average Forecast - averaged Q4 2019 forecasts of GLJ, Sproule, McDaniel and AJM Deloitte. BMO Research Average as of January 1, 2020.
1. This page does not include Northwest Territories well production.
AECO / NYMEX HISTORICAL STATION 2/ AECO HISTORICAL
WESTERN CANADA GAS STORAGE U.S. NATURAL GAS STORAGE
AECO GAS PRICE FORECASTS WCSB GAS PRODUCTION(1)
$0$1$2$3$4$5$6
$0$1$2$3$4$5$6
Dec-18 Mar-19 Jun-19 Sep-19 Dec-19 Mar-20Di
ff (U
S$/M
MBT
U)
AEC
O (
C$/
MM
BTU)
HH - AECO Diff (US$/MMBTU) AECO
$0
$1
$2
$3
$0
$1
$2
$3
$4
Dec-18 Mar-19 Jun-19 Sep-19 Dec-19 Mar-20
Diff
(C$/
MM
BTU)
St. 2
BC
(C$/
MM
BTU)
AECO - St.2 Diff (C$/MMBTU) Station 2 BC
0
5
10
15
20
2012 2013 2014 2015 2016 2017 2018 2019 2020
Natu
ral G
as P
rodu
ctio
n (B
cf/d
)
BC AB SK MB
March 05-2020
0
50
100
150
200
250
300
350
2012 2013 2014 2015 2016 2017 2018 2019
Pro
duct
ion
(Mbo
e/d)
Shell Petronas Painted Pony TourmalinePacific Canbriam Canadian Natural Crew Other
-$1.00
$0.00
$1.00
$2.00
$3.00
$4.00
$5.00
2018 2019 2020
Natu
ral G
as P
rice
(US$
/MM
BTU)
Henry Hub Dawn Chicago City Gate AECO Station 2
8 Source: BMO Capital Markets, Bloomberg 1. TC Energy. 2. NMML production area defined by wells on Pipeline Route & Market Access Map. Note: NMML – North Montney Mainline
North Montney Mainline – Increased Access to Additional Gas Markets
NORTH AMERICAN GAS MARKET PRICING
PIPELINE ROUTE & MARKET ACCESS MAP PROJECT TIMELINE(1)
PIPELINE DESIGN AND MARKET ACCESS(1)
The NMML is a 42” diameter pipeline, operated by TC Energy, spanning 206 km from the existing Saturn section to the Blair Creek receipt point
The first segment of the project (Groundbirch compressor station Aitken Creek) was put into service in February 2020
The NMML is expected to add up to 2.4 Bcf/d with 14 different metering stations with multiple access points to tie into the pipeline. The pipeline adds an additional egress point out of NEBC and exposure beyond Station 2. Other key lines include Enbridge, North River & Alliance
The project will enable Northeast BC gas to access Alberta and various North American gas markets through the NGTL system
NEBC gas production has undergone significant production growth introducing the need for additional egress options and multiple pipeline projects for the area
Over 300% production
growth since 2012
2011
Initiated landowner, Indigenous, and
Stakeholder engagement
2017
Filed variance application and meter station applications
with NEB
Received Project Approval from the
NEB
2015
Construction commences per
regulatory approval
2017
Q1 2020
Aitken Creek section and Groundbrich
Compressor Station placed into service
Kahta section & Saturn Compressor Station to be placed
into service
Q2 2020
NMML MONTNEY CATCHMENT PRODUCTION GROWTH(2)
Station 2 Groundbirch Compressor
Station
McMahon
Townsend
Aitken Creek
Saturn Compressor
Station
HH, Dawn & Chicago historically have stronger
prices and less volatility than AECO & Station 2
Blair Creek
March 05-2020
0
50
100
150
200
250
300
Act
ive
Rig
Cou
nt
AB SK BC MB Previous Year Activity
0 2 4 6 8 10 12 14
Crescent Point
Tourmaline
Husky
Canadian Natural
Cenovus
Seven Generations
Suncor
Baytex
Vermilion
Whitecap
Grande Prairie Central AB SK Area IVPeace River / Slave Lk. Athabasca / Cold Lk. NEBCSK Area II SK Area I Fort McMurraySE AB SK Area III E.Central AB
ACTIVE RIG COUNT BY AREA – 206 ACTIVE RIGS(1) IN THE WEEK ENDING FEBRUARY 28, 2020
9
Rig Analysis
Source: DOB, BMO Capital Markets 1. Based on DOB Weekly Drilling Report ending on February 28, 2020 2. Based on DOB Rig Activity ending on February 25, 2020
PSAC Area
Active Rig Count
SASKATCHEWAN
ALBERTA
BRITISH COLUMBIA
SK Area I 14
Athabasca/Cold Lk 18
Fort McMurray 12
SK Area IV 20
SK Area III 5
Rainbow Lk 1 NEBC
18
Peace River/Slave Lk. 19
E. Central AB 9
SK Area II 14
Active Rigs Shown
Central AB 24
51% of rig count
Grande Prairie 42
Foothills 2
WEEKLY RIG COUNT BY PROVINCE(2) TOP OPERATORS BY RIG COUNT(1)
SE AB 8
218 Rigs were active this
time last year
March 05-2020
Wells Spud Oil and Raw Gas ProductionFeb-20 vs. Feb-19 Direction Dec-19 vs. Nov-19 vs. Oct-19 vs. Dec-18 Direction
(well count) (%) (boe/d) (%) (%) (%)
Viking 108 (3%) 151,051 (1%) 1% (3%)
BC Montney 22 (44%) 899,512 2% 5% 1%
AB Montney 28 (24%) 616,281 (2%) 3% 4%
Duvernay WSB 27 59% 116,108 (2%) 3% 22%
Duvernay ESB 4 (33%) 20,902 9% 12% 15%
Spirit River 12 33% 377,941 3% 4% (22%)
Cardium 22 (37%) 207,409 3% 3% (1%)
Bakken 25 (31%) 69,507 2% 4% (3%)
SE Sask Mississippian 55 (37%) 132,366 (0%) (1%) (9%)
Sub-Total 303 (20%) 2,591,077 1% 4% (3%)
Other 338 (41%) 1,789,655 1% 5% (1%)
Total 641 (33%) 4,380,732 0.7% 4.4% (2.4%)
0
1
2
3
4
5
2012 2013 2014 2015 2016 2017 2018 2019 2020
Tota
l Pro
duct
ion
(MM
boe/
d)
Other VikingAB Montney BC MontneySE Sask Mississippian Spirit RiverBakken Duvernay WSBDuvernay ESB Cardium
For use on pages 11-19, we define the following well classifications: Location and Drilling wells defined as wells licensed or licensed and spud in the last twelve months (LTM), with no rig release date on record. Standing wells are defined as wells that have not produced but have a rig release date within the LTM. Producing wells include water injectors that support production All wells with no production and a rig release prior to January 2012 are not shown. All wells with no production in LTM not shown. As of the August 2018 Market Monitor, thermal production in Saskatchewan is now excluded from the “Other” play category. Production volumes are raw.
10
WCSB Key Play Activity
Source: BMO Capital Markets, geoSCOUT, GeoEdges Note: This page does not include mining or thermal production or conventional wells from the Northwest Territories Production as of December 2019; Spud and license data as of March 2, 2020
1. LTM is 13 month rolling window
0
250
500
750
1,000
1,250
Feb-19 May-19 Aug-19 Nov-19 Feb-20
Wel
l Eve
nts
Spud
(cou
nt)
Other Viking BC MontneyAB Montney Duvernay WSB Duvernay ESBSpir it River Cardium BakkenSE Sask Mississippian
0.0
0.5
1.0
1.5
2.0
2.5
Feb-19 May-19 Aug-19 Nov-19 Feb-20
Met
res
Dri
lled
(mill
ions
)
Other Viking BC MontneyAB Montney Duvernay WSB Duvernay ESBSpir it River Cardium BakkenSE Sask Mississippian
LOCATOR MAP PRODUCTION BY PLAY(1)
METRES DRILLED BY PLAY LTM(1) WELLS SPUD BY PLAY(1)
PLAY SUMMARY – WELLS SPUD AND TOTAL PRODUCTION
March 05-2020
Current Last Month Last Year(Feb-20) (Jan-20) (Feb-19)
Licensing Count 45 98 44Spud Count 108 154 111
0
50
100
150
200
Feb-19 May-19 Aug-19 Nov-19 Feb-20
Wells Licensed Wells Spud 13mo Licensing Avg
-
50
100
150
200
2012 2013 2014 2015 2016 2017 2018 2019 2020Prod
uctio
n (M
boe/
d)
Pre-2012 2012 2013 2014 20152016 2017 2018 2019
0 500 1,000 1,500 2,000 2,500 3,000
TeineBaytex
WhitecapCrescent Point
Tamarack Valley
Producing Standing Location and Drilling
11
Viking
Viking Snapshot
Source: BMO Capital Markets, Bloomberg, geoSCOUT, GeoEdges Note: Production as of December 2019; Spud and license data as of March 2, 2020 1. As defined on page 10
2. Excludes royalty transactions. 3. Deal metrics shown include entire corporate transaction, not just the Viking assets 4. Karve’s acquisition of High Ground for an undisclosed amount.
2
1
3
1
3
1 1
0
0.5
1
1.5
2
2.5
3
3.5
$0
$50,000
$100,000
$150,000
Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1
2015 2016 2017 2018 2019 2020
Avg. $/boe/d #Deals
Last Announced Deal: July 2019(4)
Parameters MetricsProd. %Gas P+P RLI (P+P) EV/boe/d EV/2P EV/DACF
(C$MM) (boe/d) (%) (Mboe) (Years) (C$/boe/d) (C$/boe) (x)18-Jun-18 Baytex Raging River Corp $1,935 24,118 7% 106,652 12.1 $80,246 $18.15 4.9x15-Aug-17 Karve Energy Apache (Alberta Viking Assets) Asset $118 6,500 57% 16,800 7.1 $18,154 $7.02 4.6x13-Dec-16 Steelhead Toro Corp $40 658 40% 4,647 19.3 $60,000 $8.50 nmf28-Nov-16 Raging River Northern Blizzard (Viking Assets) Asset $58 620 3% 5,800 25.6 $93,548 $10.00 6.1x2-Nov-16 Tamarack Valley Spur (Viking) PrivateCo $388 6,250 48% 26,500 11.6 $62,150 $14.66 6.0x20-Jul-16 Raging River Rock (Forgan Lands) Asset $25 100 0% n.a. n.a. $251,000 n.a. n.a.10-Jun-16 Teine Energy Penn West (Viking Assets) Asset $975 16,300 9% 53,200 8.9 $59,816 $18.33 12.9x31-May-16 Raging River Rock Energy Corp $109 2,550 5% 17,077 18.3 $42,745 $6.38 6.6x10-May-16 NAL Resources Husky (Viking) Asset $102 1,470 45% n.a. n.a. $69,388 n.a. n.a.Average - Viking $417 6,507 24% 32,954 14.7 $81,894 $11.86 6.8xMedian - Viking $109 2,550 9% 17,077 12.1 $62,150 $10.00 6.0x
ROYALTY27-Feb-18 PrairieSky Undisclosed (AB Viking Royalty Assets) Asset $46 300 54% n.a. n.a. $153,333 n.a. n.a.2-Mar-17 Freehold Undisclosed (Royalty Assets) Asset $34 185 9% n.a. n.a. $183,784 n.a. n.a.
AnnounceDate Acquiror Target Corp/Asset Enterprise
Value
TRANSACTION ACTIVITY (2016 TO PRESENT)(2)
PRODUCTION BY DRILLING YEAR TOP 5 OPERATORS BY HORIZONTAL WELL COUNT(1)
Activity down from last month but consistent with one year
ago
(3)
(3)
TRANSACTION 2P RESERVES MULTIPLES ($/BOE) TRANSACTION PRODUCTION MULTIPLES ($/BOE/D)
~$251k/boe/d
2
1 1
3
1 1
0
0.5
1
1.5
2
2.5
3
3.5
$0
$5
$10
$15
$20
Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1
2015 2016 2017 2018 2019 2020
Avg. $/boe #Deals
Viking Horizontal Wells
ACTIVITY OVERVIEW MAP
March 05-2020
0 200 400 600 800 1,000 1,200
OvintivPetronas
TourmalineARCShell
Producing Standing Location and Drilling
-
250
500
750
1,000
2012 2013 2014 2015 2016 2017 2018 2019 2020Prod
uctio
n (M
boe/
d)
Pre-2012 2012 2013 2014 20152016 2017 2018 2019
0
40
80
120
160
Feb-19 May-19 Aug-19 Nov-19 Feb-20
Wells Licensed Wells Spud 13mo Licensing Avg
Current Last Month Last Year(Feb-20) (Jan-20) (Feb-19)
Licensing Count 23 85 25Spud Count 22 47 39
Parameters Metrics
Prod. %Gas P+P RLI (P+P) EV/boe/d EV/2P EV/DACF(C$MM) (boe/d) (%) (Mboe) (Years) (C$/boe/d) (C$/boe) (x)
24-Feb-20 Tourmaline Chinook Energy (NE BC Montney) Corp $24 3,500 86% 35,600 27.9 $6,971 $0.69 n.a.18-Oct-19 Tourmaline Painted Pony (NE BC Montney) Asset $45 -- n.a. n.a. n.a. n.a. n.a. n.a.31-Jul-18 Undisclosed Canbriam (NE BC Montney) Asset $50 n.a. n.a. n.a. n.a. n.a. n.a. n.a.8-May-17 Primavera Crew (Goose Assets) Asset $49 n.a. n.a. n.a. n.a. n.a. n.a. n.a.23-Mar-17 ConocoPhillips Pengrowth (Bernadet) Asset $92 n.a. n.a. n.a. n.a. n.a. n.a. n.a.15-Mar-17 Painted Pony UGR PrivateCo $271 8,500 99% 325,100 104.8 $31,914 $0.83 8.9x20-Oct-16 Tourmaline Shell (Deep Basin / Montney) Asset $1,369 24,850 85% 473,500 52.2 $55,091 $2.89 n.a.Average - BC Montney $272 9,213 90% 278,067 61.6 $31,325 $1.47 8.9xMedian - BC Montney $50 6,000 86% 325,100 52.2 $31,914 $0.83 8.9x
Enterprise Value
AnnounceDate Acquiror Vendor Corp/Asset
1
2
1
2 2
1 1 1
0
0.5
1
1.5
2
2.5
$0
$20,000
$40,000
$60,000
$80,000
$100,000
$120,000
Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1
2015 2016 2017 2018 2019 2020
Avg. $/boe/d #Deals
1
2
1
2 2
1 1 1
0
0.5
1
1.5
2
2.5
$0
$5
$10
$15
$20
Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1
2015 2016 2017 2018 2019 2020
Avg. $/boe #Deals
12
BC Montney
BC Montney Horizontal Wells
Source: BMO Capital Markets, Bloomberg, geoSCOUT, GeoEdges Note: Production as of December 2019; Spud and license data as of March 2, 2020 1. As defined on page 10
2. Excludes Suncor’s divesture of NEBC mineral land holdings and subsequent equity stake in Canbriam and Pacific Oil & Gas’ acquisition of Canbriam for an undisclosed amount
BC Montney Snapshot Last Announced Deal: $24MM in February 2020
Activity decreased from last month
PRODUCTION BY DRILLING YEAR TOP 5 OPERATORS BY HORIZONTAL WELL COUNT(1)
TRANSACTION ACTIVITY (2016 TO PRESENT)(2)
TRANSACTION 2P RESERVES MULTIPLES ($/BOE)
~$153k/boe/d
TRANSACTION PRODUCTION MULTIPLES ($/BOE/D)
ACTIVITY OVERVIEW MAP
March 05-2020
0 200 400 600 800
Seven GenerationsBirchcliff
ParamountOvintiv
NuVista
Producing Standing Location and Drilling
-
250
500
750
2012 2013 2014 2015 2016 2017 2018 2019 2020Prod
uctio
n (M
boe/
d)
Pre-2012 2012 2013 2014 20152016 2017 2018 2019
Current Last Month Last Year(Feb-20) (Jan-20) (Feb-19)
Licensing Count 48 28 37Spud Count 28 52 37
020406080
100
Feb-19 May-19 Aug-19 Nov-19 Feb-20
Wells Licensed Wells Spud 13mo Licensing Avg
1 1 1 1 1 12 2 2
12
0
1
2
3
4
5
6
7
8
$0
$40,000
$80,000
$120,000
Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1
2015 2016 2017 2018 2019 2020
Avg. $/boe/d #Deals
13
Parameters Metrics
Prod. %Gas P+P RLI (P+P) EV/boe/d EV/2P EV/DACF(C$MM) (boe/d) (%) (Mboe) (Years) (C$/boe/d) (C$/boe) (x)
14-Nov-18 Birchcliff ORLEN (Pouce Coupe Assets) Asset $39 700 86% -- n.a. $55,714 n.a. n.a.30-Oct-18 Pipestone Blackbird Corp $247 1,148 45% 59,099 141.0 $215,262 $4.18 19.7x10-Sep-18 Velvet Iron Bridge Corp $142 2,314 70% 26,113 30.9 $61,379 $5.44 14.5x9-Aug-18 NuVista Cenovus (Pipestone Partnership) Asset $625 9,600 54% 156,888 44.8 $65,104 $3.98 9.9x14-Jun-18 Strath Paramount (Resthaven/Jayar) Corp $340 5,300 64% 8,100 4.2 $64,151 $41.98 n.a.1-Sep-17 Tangle Creek RMP (Waskahigan) Asset $80 3,215 70% 23,000 19.6 $24,883 $3.48 n.a.6-Jul-17 Paramount Trilogy Corp $1,109 25,133 62% 165,059 18.0 $44,112 $6.72 6.3x1-May-17 Undisclosed Trilogy (Valhalla) Asset $50 1,100 84% 5,500 13.7 $45,455 $9.09 n.a.1-May-17 Undisclosed Paramount (Valhalla) Asset $150 1,400 88% n.a. n.a. $107,143 n.a. n.a.5-Apr-17 Leucrotta Undisclosed (Mica/Doe) Asset $36 n.a. n.a. n.a. n.a. n.a. n.a. n.a.4-Jan-17 Undisclosed Kelt (Karr Assets) Asset $100 1,303 50% 12,700 26.7 $76,746 $7.87 n.a.31-Oct-16 Enerplus RMP (Ante Creek Assets) Asset $114 4,300 55% 10,001 6.4 $26,581 $11.43 n.a.6-Jul-16 Seven Generations Paramount (Musreau Assets) Asset $1,897 30,000 44% 293,000 26.8 $63,219 $6.47 n.a.21-Jun-16 Birchcliff Encana (Gordondale Assets) Asset $625 26,000 59% 191,133 20.1 $24,038 $3.27 n.a.16-Mar-16 Enercapita Surge (Sunset Assets) Asset $28 700 n.a. n.a. n.a. $40,000 n.a. n.a.Average - AB Montney $372 8,015 64% 79,216 32.0 $65,271 $9.45 12.6xMedian - AB Montney $142 2,764 62% 24,557 20.1 $58,547 $6.47 12.2x
AnnounceDate Acquiror Vendor Corp/Asset Enterprise
Value
Last Announced Deal: $39MM in November 2018 AB Montney Snapshot
Source: BMO Capital Markets, Bloomberg, geoSCOUT, GeoEdges Note: Production as of December 2019; Spud and license data as of March 2, 2020
1. As defined on page 10 2. Reflects full corporate transaction
AB Montney
AB Montney Horizontal Wells Activity up and
production increased by
4% YoY
PRODUCTION BY DRILLING YEAR TOP 5 OPERATORS BY HORIZONTAL WELL COUNT(1)
TRANSACTION ACTIVITY (2016 TO PRESENT)
TRANSACTION 2P RESERVES MULTIPLES ($/BOE)
~$135k/boe/d
(2)
TRANSACTION PRODUCTION MULTIPLES ($/BOE/D)
1 1 1 1 1 1
2 2 2
1
2
0
0.5
1
1.5
2
2.5
$0$5
$10$15$20$25$30$35
Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1
2015 2016 2017 2018 2019 2020
Avg. $/boe #Deals
ACTIVITY OVERVIEW MAP
March 05-2020
0 100 200 300 400
ShellChevron
OvintivXTO
Murphy
Producing Standing Location and Drilling
- 25 50 75
100 125
2012 2013 2014 2015 2016 2017 2018 2019 2020Prod
uctio
n (M
boe/
d)
Pre-2012 2012 2013 2014 20152016 2017 2018 2019
0
10
20
30
40
Feb-19 May-19 Aug-19 Nov-19 Feb-20
Wells Licensed Wells Spud 13mo Licensing Avg
Current Last Month Last Year(Feb-20) (Jan-20) (Feb-19)
Licensing Count 1 11 24Spud Count 27 17 17
14
Duvernay West Shale Basin Snapshot Last Announced Deal: $1.1B in July 2017(3)
Duvernay WSB
Spuds up and production
holding flat YoY
Compensation Parameters Metrics (Adjusted)Upfront Total Interest Acres Production Resource Acreage Resource
($MM) ($MM) (%) (mcfe/d) (tcf) (C$/Acre) (C$/Mcfe)
6-Jul-17 Paramount Trilogy n.a. n.a. 100% 118,000 n.a. n.a. n.a. n.a.25-May-17 XTO Trilogy $60 $60 100% 6,240 3,840 n.a. $6,026 n.a.27-Jan-16 Murphy Oil Athabasca $250 $475 61% 158,000 28,440 1.00 $1,877 $0.307-Dec-15 XTO Yoho $50 $50 100% 10,290 5,340 n.a. $1,832 n.a.19-Nov-15 Undisclosed Trilogy $113 $113 100% 5,760 3,480 n.a. $16,055 n.a.6-Oct-14 KUFPEC Chevron <$1,678 $1,678 30% 99,000 4,590 n.a. $16,678 n.a.1-Aug-13 Chevron Alta Energy $900 $900 100% 67,900 -- n.a. $13,255 n.a.13-Dec-12 PetroChina Encana $1,180 $2,180 50% 222,055 -- 6.74 $9,817 $0.32Average - Duvernay $604 $779 85,906 6,527 3.87 $9,363 $0.31Median - Duvernay $250 $475 83,450 3,840 3.87 $9,817 $0.31
AnnounceDate Acquiror Vendor
Source: BMO Capital Markets, Bloomberg, geoSCOUT, GeoEdges Note: Production as of December 2019; Spud and license data as of March 2, 2020. 1. As defined on page 10 2. Production multiple adjusted assuming $30,000/boe/d.
3. Paramount’s acquisition of Trilogy is a corporate transaction 4. Transaction value includes a carry of a portion of Chevron Canada’s share of the joint venture’s
future capital costs; amount unknown
PRODUCTION BY DRILLING YEAR TOP 5 OPERATORS BY HORIZONTAL WELL COUNT(1)
TRANSACTION ACTIVITY (2012 TO PRESENT)
TRANSACTION MULTIPLES ($/MCFE) TRANSACTION ACREAGE MULTIPLES ($/ACRE)
(3)
(4)
(2)
1
0
0.2
0.4
0.6
0.8
1
1.2
$0.0
$0.1
$0.2
$0.3
$0.4
$0.5
Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1
2015 2016 2017 2018 2019 2020
Avg. $/Mcfe #Deals
2
1 1 1
0
0.5
1
1.5
2
2.5
$0
$5,000
$10,000
$15,000
$20,000
Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1
2015 2016 2017 2018 2019 2020
Avg. $/Acre #Deals
Duvernay Horizontal Wells
ACTIVITY OVERVIEW MAP
March 05-2020
15
Duvernay East Shale Basin Snapshot
Source: BMO Capital Markets, Bloomberg, geoSCOUT, GeoEdges Note: Production as of December 2019; Spud and license data as of March 2, 2020 1. As defined on page 10 2. Journey and Kiwetinohk deal is a joint venture agreement
3. Baytex’s acquisition of Raging River was a corporate transaction
Last Announced Deal: August 2018
Duvernay ESB
- 5
10 15 20 25
2012 2013 2014 2015 2016 2017 2018 2019 2020
Prod
uctio
n (M
boe/
d)
2012 2013 2014 2015 2016 2017 2018 2019
0 50 100 150
VestaArtis
PrairieThunderChronos
Baytex
Producing Standing Location and Drilling
Compensation Parameters Metrics (Adjusted)Upfront Total Interest Acres Production Resource Acreage Resource
($MM) ($MM) (%) (mcfe/d) (tcf) (C$/Acre) (C$/Mcfe)
29-Aug-18 Kiwetinohk Journey (JV) n.a. n.a. n.a. 89,600 n.a. n.a. n.a. n.a.18-Jun-18 Baytex Raging River (Corporate) n.a. n.a. n.a. n.a. n.a. n.a. n.a. n.a.Average - Duvernay n.a. n.a. 89,600 n.a. n.a. n.a. n.a.Median - Duvernay n.a. n.a. 89,600 n.a. n.a. n.a. n.a.
AnnounceDate Acquiror Vendor
02468
1012
Feb-19 May-19 Aug-19 Nov-19 Feb-20
Wells Licensed Wells Spud 13mo Licensing Avg
Current Last Month Last Year(Feb-20) (Jan-20) (Feb-19)
Licensing Count 6 2 0Spud Count 4 7 6
Activity increasing
YoY
PRODUCTION BY DRILLING YEAR TOP 5 OPERATORS BY HORIZONTAL WELL COUNT(1)
TRANSACTION ACTIVITY (2018 – PRESENT)(2,3)
Duvernay Horizontal Wells
ACTIVITY OVERVIEW MAP
March 05-2020
0 200 400 600 800 1,000
PeytoTourmaline
BellatrixJupiter
Cenovus
Producing Standing Location and Drilling
- 100 200 300 400 500 600
2012 2013 2014 2015 2016 2017 2018 2019 2020Prod
uctio
n (M
boe/
d)
Pre-2012 2012 2013 2014 20152016 2017 2018 2019
05
1015202530
Feb-19 May-19 Aug-19 Nov-19 Feb-20
Wells Licensed Wells Spud 13mo Licensing Avg
Current Last Month Last Year(Feb-20) (Jan-20) (Feb-19)
Licensing Count 14 9 20Spud Count 12 18 9
1 1 1
2
1
2
0
0.5
1
1.5
2
2.5
$0
$10,000
$20,000
$30,000
$40,000
$50,000
$60,000
Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1
2015 2016 2017 2018 2019 2020
Avg. $/boe/d #Deals
Parameters MetricsProd. %Gas P+P RLI (P+P) EV/boe/d EV/2P EV/DACF
(C$MM) (boe/d) (%) (Mboe) (Years) (C$/boe/d) (C$/boe) (x)
29-Mar-17 Cenovus ConocoPhillips (FCCL & D. Basin Assets) Asset $17,730 284,396 31% 3,965,833 38.2 $62,341 $4.47 9.8x20-Oct-16 Tourmaline Shell (Deep Basin & Gundy Montney) Asset $1,369 24,850 85% 473,500 52.2 $55,091 $2.89 n.a.16-Jun-16 Bellatrix Grafton (Ferrier Assets) Asset $29 2,000 79% n.a. n.a. $14,599 n.a. n.a.13-Jun-16 Undisclosed NuVista (Cretaceous Wapiti) Asset $70 3,200 73% 21,700 18.6 $21,875 $3.23 n.a.11-Jan-16 Tourmaline / Undisc. Enerplus (Deep Basin Assets) Asset $193 5,400 98% n.a. n.a. $35,741 n.a. n.a.Average - Spirit River $3,878 63,969 73% 1,487,011 36.3 $37,929 $3.53 9.8xMedian - Spirit River $193 5,400 79% 473,500 38.2 $35,741 $3.23 9.8x
AnnounceDate Acquiror Vendor Corp/Asset Enterprise
Value
16 Source: BMO Capital Markets, Bloomberg, geoSCOUT, GeoEdges Note: Production as of December 2019; Spud and license data as of March 2, 2020 1. As defined on page 10
2. Deal metrics shown include entire transaction (including non-Spirit River assets, which are significant)
Spirit River Snapshot
Spirit River
Activity holding flat and
consistent with one year ago
Last Announced Deal: $17.7B in March 2017(2)
PRODUCTION BY DRILLING YEAR TOP 5 OPERATORS BY HORIZONTAL WELL COUNT(1)
TRANSACTION ACTIVITY (2016 TO PRESENT)
TRANSACTION 2P RESERVES MULTIPLES ($/BOE)
(2)
TRANSACTION PRODUCTION MULTIPLES ($/BOE/D)
1 1
2
1
2
0
0.5
1
1.5
2
2.5
$0
$2
$4
$6
$8
$10
$12
Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1
2015 2016 2017 2018 2019 2020
Avg. $/boe #Deals
Spirit River Horizontal Wells
ACTIVITY OVERVIEW MAP
March 05-2020
0102030405060
Feb-19 May-19 Aug-19 Nov-19 Feb-20
Wells Licensed Wells Spud 13mo Licensing Avg
17 Source: BMO Capital Markets, Bloomberg, geoSCOUT, GeoEdges Note: Production as of December 2019; Spud and license data as of March 2, 2020 1. As defined on page 10
2. Does not include the take-private of Lightstream (now called Ridgeback) 3. Does not include royalty transactions
Cardium Snapshot
Cardium
Activity decreased YoY with production
holding flat
Current Last Month Last Year(Feb-20) (Jan-20) (Feb-19)
Licensing Count 18 35 28Spud Count 22 38 35
- 50
100 150 200 250 300
2012 2013 2014 2015 2016 2017 2018 2019 2020Prod
uctio
n (M
boe/
d)
Pre-2012 2012 2013 2014 20152016 2017 2018 2019 0 200 400 600
WhitecapRidgeback
BonterraObsidian
Peyto
Producing Standing Location and Drilling
Parameters Metrics
Prod. %Gas P+P RLI (P+P) EV/boe/d EV/2P EV/DACF(C$MM) (boe/d) (%) (Mboe) (Years) (C$/boe/d) (C$/boe) (x)
11-Jul-17 NAL Resources Pengrowth (Olds/Garrington Assets) Asset $300 13,875 n.a. 78,000 15.4 $21,622 $3.85 n.a.14-Jun-17 Undisclosed Bellatrix (Strachan Assets) Asset $35 1,750 70% n.a. n.a. $19,714 n.a. n.a.5-Dec-16 TransGlobe Bellatrix (Harmattan Assets) Asset $80 3,104 43% 21,300 18.8 $25,773 $3.76 n.a.19-Sep-16 InPlay Bellatrix (Pembina Assets) Asset $47 900 25% 7,900 24.0 $51,782 $5.90 n.a.19-Sep-16 InPlay Anderson Corp $33 1,659 58% 6,517 10.8 $19,640 $5.00 6.5x28-Jul-16 ARC Resources Husky & Penn West (Pembina) Asset $148 3,083 15% n.a. n.a. $48,000 n.a. n.a.7-Jun-16 Gear Energy Striker Corp $64 2,000 40% 11,068 15.2 $31,850 $5.76 13.8xAverage - Cardium $101 3,767 42% 24,957 16.8 $31,197 $4.85 10.1xMedian - Cardium $64 2,000 42% 11,068 15.4 $25,773 $5.00 10.1x
AnnounceDate Acquiror Vendor Corp/Asset Enterprise
Value
PRODUCTION BY DRILLING YEAR TOP 5 OPERATORS BY HORIZONTAL WELL COUNT(1)
TRANSACTION ACTIVITY(2)(3) (2016 TO PRESENT)
TRANSACTION 2P RESERVES MULTIPLES ($/BOE) TRANSACTION PRODUCTION MULTIPLES ($/BOE/D)
1 1 1
2
1 1
0
0.5
1
1.5
2
2.5
$0
$5
$10
$15
$20
$25
Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1
2015 2016 2017 2018 2019 2020
Avg. $/boe #Deals
1 1 1
3
1 1 1
0
0.5
1
1.5
2
2.5
3
3.5
$0
$20,000
$40,000
$60,000
$80,000
$100,000
$120,000
Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1
2015 2016 2017 2018 2019 2020
Avg. $/boe/d #Deals
Cardium Horizontal Wells
ACTIVITY OVERVIEW MAP
Last Announced Deal: $52MM GORR in Dec 2017
March 05-2020
- 25 50 75
100 125
2012 2013 2014 2015 2016 2017 2018 2019 2020
Prod
uctio
n (M
boe/
d)
Pre-2012 2012 2013 2014 20152016 2017 2018 2019
0 500 1,000 1,500 2,000 2,500 3,000
Crescent PointTundra
RidgebackTORC
Vermilion
Producing Standing Location and Drilling
Parameters Metrics
Prod. %Gas P+P RLI (P+P) EV/boe/d EV/2P EV/DACF(C$MM) (boe/d) (%) (Mboe) (Years) (C$/boe/d) (C$/boe) (x)
23-Jul-18 Gear Steppe PrivateCo $70 1,175 1% n.a. n.a. $59,915 n.a. 2.9x
15-Jan-18 Vermilion Red River PrivateCo $91 1,150 0% 6,700 16.0 $78,957 $13.55 4.2x
23-Apr-14 Crescent Point CanEra PrivateCo $1,113 10,000 4% 52,100 14.3 $111,340 $21.37 4.8x
14-Mar-12 Crescent Point Reliable Corp $107 1,100 0% 4,100 10.2 $97,378 $26.13 4.1x
16-Feb-12 Crescent Point PetroBakken (Bakken Assets) Asset $427 2,900 10% 12,600 11.9 $147,241 $33.89 6.4x
Average - Bakken $362 3,265 3% 18,875 13.1 $98,966 $23.73 4.5xMedian - Bakken $107 1,175 1% 9,650 13.1 $97,378 $23.75 4.2x
AnnounceDate Acquiror Vendor Corp/Asset Enterprise
Value
01020304050
Feb-19 May-19 Aug-19 Nov-19 Feb-20
Wells Licensed Wells Spud 13mo Licensing Avg
Current Last Month Last Year(Feb-20) (Jan-20) (Feb-19)
Licensing Count 17 22 12Spud Count 25 40 36
Bakken Horizontal Wells
18 Source: BMO Capital Markets, Bloomberg, geoSCOUT, GeoEdges Note: Production as of December 2019; Spud and license data as of March 2, 2020 1. The Torquay and Three Forks are included as part of the Bakken sub-group 2. In Manitoba, licensing may not specify target formation, and as a result wells will be correctly
categorized after they are drilled 3. As defined on page 10 4. Does not include the take-private of Lightstream (now called Ridgeback)
Bakken Snapshot(1)
Bakken
ACTIVITY OVERVIEW MAP
PRODUCTION BY DRILLING YEAR
1 1
0
0.5
1
1.5
2
2.5
3
$0
$5
$10
$15
$20
$25
$30
$35
Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1
2015 2016 2017 2018 2019 2020
Avg. $/boe #Deals
1 1
0
0.5
1
1.5
2
2.5
3
$0
$25,000
$50,000
$75,000
$100,000
$125,000
$150,000
Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1
2015 2016 2017 2018 2019 2020
Avg. $/boe/d #Deals
TOP 5 OPERATORS BY HORIZONTAL WELL COUNT(2)(3)
TRANSACTION 2P RESERVES MULTIPLES ($/BOE) TRANSACTION PRODUCTION MULTIPLES ($/BOE/D)
Spuds down 30% and
licensing up 42% YoY
TRANSACTION ACTIVITY(4) (2012 TO PRESENT)
Last Announced Deal: $70MM in July 2018
March 05-2020
020406080
100120
Feb-19 May-19 Aug-19 Nov-19 Feb-20
Wells Licensed Wells Spud 13mo Licensing Avg
ACTIVITY
Parameters Metrics
Prod. %Gas P+P RLI (P+P) EV/boe/d EV/2P EV/DACF(C$MM) (boe/d) (%) (Mboe) (Years) (C$/boe/d) (C$/boe) (x)
3-Sep-19 Undisclosed Crescent Point (SE SK Assets) Asset $212 7,000 15% 49,200 19.3 $30,286 $4.31 4.5x8-Aug-18 TORC Villanova 4 PrivateCo $62 1,000 20% 4,000 11.0 $61,642 $15.41 n.a.8-May-18 TORC Crescent Point (SE SK Assets) Asset $225 3,200 n.a. 15,500 13.3 $70,281 $14.51 n.a.16-Apr-18 Vermilion Spartan Corp $1,396 23,000 9% 113,485 13.5 $60,684 $12.30 4.3x13-Nov-17 Whitecap Cenovus (Weyburn Unit) Asset $940 14,800 0% 121,409 22.5 $63,514 $7.74 6.7x1-Jun-17 Cardinal Apache (SE SK & House Mountain Assets) Asset $330 5,000 0% 28,600 15.7 $66,000 $11.54 6.0x10-May-17 Undisclosed Freehold (SE Sask Assets) Asset $29 750 44% n.a. n.a. $38,533 n.a. n.a.17-Nov-16 Spartan ARC (SE Sask Assets) Asset $700 7,500 2% 39,300 14.4 $93,333 $17.81 8.2x3-Aug-16 Spartan Kinwest (SE Sask Assets) Asset $24 450 7% n.a. n.a. $53,333 n.a. n.a.25-Jul-16 TORC Zargon (SE Sask Assets) Asset $96 1,200 4% n.a. n.a. $79,583 n.a. n.a.29-Jun-16 Spartan Halo / Other (SE Sask Assets) Asset $62 1,500 1% 7,176 13.1 $41,467 $8.67 5.7x19-May-16 Spartan Wyatt Oil + Gas PrivateCo $77 1,330 24% 14,629 30.1 $57,895 $5.26 6.8xAverage - SE Sask $346 5,561 11% 43,700 17.0 $59,713 $10.84 6.0xMedian - SE Sask $154 2,350 7% 28,600 14.4 $61,163 $11.54 6.0x
AnnounceDate Acquiror Vendor Corp/Asset Enterprise
Value
19 Source: BMO Capital Markets, Bloomberg, geoSCOUT, GeoEdges Note: Production as of December 2019; Spud and license data as of March 2, 2020 1. As defined on page 10
2. In Manitoba, licensing may not specify target formation, and as a result wells will be correctly categorized after they are drilled
SE Mississippian Snapshot Last Announced Deal: $212MM in September 2019
Activity down and production declined 9%
YoY
Mississippian Current Last Month Last Year(Feb-20) (Jan-20) (Feb-19)
Licensing Count 54 81 67Spud Count 55 87 87
-
50
100
150
200
2012 2013 2014 2015 2016 2017 2018 2019 2020Prod
uctio
n (M
boe/
d)
Pre-2012 2012 2013 2014 20152016 2017 2018 2019
0 500 1,000 1,500 2,000
VermilionCrescent Point
TundraTORC
Whitecap
Producing Standing Location and Drilling
ACTIVITY OVERVIEW MAP
TOP 5 OPERATORS BY HORIZONTAL WELL COUNT(1,2)
TRANSACTION ACTIVITY (2016 TO PRESENT)
TRANSACTION 2P RESERVES MULTIPLES ($/BOE) TRANSACTION PRODUCTION MULTIPLES ($/BOE/D)
1
2
1
2 2
1
2
1 1
2
1 1
0
0.5
1
1.5
2
2.5
$0
$50,000
$100,000
$150,000
$200,000
Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1
2015 2016 2017 2018 2019 2020
Avg. $/boe/d #Deals
1
2 2
1 1 1 1
2
1 1
0
0.5
1
1.5
2
2.5
$0$5
$10$15$20$25$30
Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1
2015 2016 2017 2018 2019 2020
Avg. $/boe #Deals
SE Saskatchewan Horizontal Wells
PRODUCTION BY DRILLING YEAR
March 05-2020
Cheryl Sandercock, P.Eng. Managing Director +1-403-515-1526 [email protected]
Joyce Kennedy, P.Geol. Managing Director +1-403-515-1576 [email protected]
Wendy Smith Low Managing Director +1-403-515-1528 [email protected]
Contacts
20
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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 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 C$ unless otherwise specified.
GEOLOGY Kathleen Dixon, MBA, P.Geol. Vice President +1-403-515-3654 [email protected]
Ryan Axani, P.Geol. Vice President +1-403-515-1512 [email protected]
COMMERCIAL Mandy Edwards Coordinator +1-403-515-1581 [email protected]
ENGINEERING Steve Kehoe, MESc, P.Eng. Director +1-403-515-3661 [email protected]
Jennifer Haskey, P.Eng. Vice President +1-403-515-1558 [email protected]
Jason Beekhuizen, MBA, P.Eng. Associate +1-403-515-1596 [email protected]
Maureen Jarvis, CET Associate +1-403-515-1537 [email protected]
INVESTMENT BANKING Sam Di Pinto Associate +1-403-515-1534 [email protected]
Taya Hanson Analyst +1-403-515-1551 [email protected]
GLOBAL MARKETS Leigh MacComb Associate +1-403-515-3694 [email protected]
Tom Widdowson Analyst +1-403-515-3682 [email protected]
March 4, 2020
Price Change Price Change Price Apr20 Apr20-Oct20 Nov20-Mar21
Prompt $1.827 $0.027 ($0.53) ($0.005) $1.65 Chi Citygate ($0.16) ($0.23) $0.03
CIG, Rockies ($0.45) ($0.56) ($0.37)
Apr20-Oct20 $1.970 $0.029 ($0.68) $0.001 $1.73 Dawn ($0.11) ($0.23) $0.01
Zero-Cost Collar $1.50/$2.43 $1.15/$2.06 Dominion ($0.33) ($0.46) ($0.38)
Zero-Cost Collar $1.25/$2.64 $1.00/$2.19 El Paso, Perm ($1.70) ($1.43) ($1.35)
HSC ($0.04) ($0.05) ($0.10)
Apr20-Dec20 $2.049 $0.028 ($0.71) ($0.005) $1.80 Malin ($0.31) ($0.39) ($0.06)
Zero-Cost Collar $1.50/$2.67 $1.15/$2.20 NW Rockies ($0.38) ($0.47) ($0.14)
Zero-Cost 3-Way $1.50/$2.00/$2.12 $1.15/$1.25/$2.33 Panhandle ($0.49) ($0.50) ($0.38)
PGE Citygate $0.86 $0.80 $0.64
Apr20-Jun20 $1.872 $0.027 ($0.62) ($0.001) $1.60 SoCal Gas ($0.42) ($0.15) $0.18
Jul20-Sep20 $2.029 $0.030 ($0.72) $0.003 $1.66 Station 2 ($0.60) ($0.78) ($0.89)
Jul20-Dec20 $2.137 $0.029 ($0.75) ($0.007) $1.76 Sumas ($0.43) ($0.42) $0.53
Oct20-Dec20 $2.246 $0.027 ($0.78) ($0.017) $1.86 TCO ($0.24) ($0.34) ($0.28)
Nov20-Mar21 $2.419 $0.023 ($0.85) ($0.023) $2.00 TxOk ($0.17) ($0.22) ($0.21)
Jan21-Dec21 $2.317 $0.009 ($0.89) ($0.006) $1.82 W aha ($1.94) ($1.59) ($1.50)
Jan21-Mar21 $2.482 $0.021 ($0.88) ($0.022) $2.03 NBP (GBP/THERM) £0.22 £0.24 £0.39
Station 2 Storage (BCF) Current W /W Change Last Year5 Yr. Avg.Seasonal
Next Day (C$/GJ) US Natural Gas # 2,200 -6.10% 1,539 1,946
Last Close $1.6889 CAN Natural Gas # 364 -7.17% 347 395
D/D Change 1.03% 0.52% Production (BCF/Day) Current Mo/Mo Change Last Year 5 Yr. Avg.
MTD Avg. $1.7403 US Dry Gas Production # 90.9 -1.08% 87.6 82.2
12-Mar-20 11-Mar-20 10-Mar-20 9-Mar-20 8-Mar-20 7-Mar-20 6-Mar-20 5-Mar-20 4-Mar-20 Commodities
Dry Gas Production 92.04 92.04 92.04 92.04 92.04 92.04 92.04 92.04 Calgary
LNG Sendout 0.12 0.12 0.12 0.12 0.12 0.12 0.12 0.12 (403) 515 3682
Net CAD Imports 4.80 4.80 4.80 4.80 4.80 4.80 4.80 4.80 Houston
Total Supply 96.96 96.96 96.96 96.96 96.96 96.96 96.96 96.96 (713) 546 9782
PowerBurn 27.98 28.12 28.25 28.17 27.97 28.40 27.97 27.98 New York
Industrial 23.40 23.40 23.40 23.40 23.40 23.40 23.40 23.40 (212) 605 1570
ResComm 30.58 28.11 26.88 27.54 32.32 38.60 32.25 30.75 London
Pipeloss 2.33 2.26 2.23 2.25 2.38 2.57 2.38 2.33 +44 20 766 8005
US Demand 92.86 90.47 89.33 89.94 94.64 101.55 94.58 93.03 Metals
Mexican Exports 5.32 5.32 5.32 5.32 5.32 5.32 5.32 5.32 New York
LNG Feedgas 8.58 8.58 8.58 8.58 8.58 8.58 8.58 8.58 (212) 605 1494
Total Demand 98.18 95.79 94.65 95.26 99.96 106.87 99.89 98.35
Current Weekly ChangeCanada Tota 240 -1.6%Canada Gas 77 2.7%
US Total 790 -0.1%US GAS 110 0.0%
Cana Wood 21 10.5%DJ-Niobrara 20 5.3%Eagle Ford 68 -2.9%Haynesvil le 43 2.4%Marcellus 38 0.0%Permian 411 0.5%
Utica 11 0.0%Will iston 53 0.0%
Dawn
Next Day (US$/MM)
$1.6688
$1.7851
Aeco 5a
Same Day (C$/GJ)
$1.6821
1.98%
$1.8594
5.32
8.58
103.26
$0.044
$0.007
$0.003
Natural Gas Storage & Production (Bloomberg)
Natural Gas Basis (USD/MMBTU)
35.40
2.47
The broad market for risk assets rallied as the Bank of Canada cut 50bp. Nat gas cash prices also were bid, facing resistance at the $1.818 10-day moving average, before rallying highe ahead of Thursday’s inventory report. Consensus is for stockpiles to decline by 125 Bcf. We see flows on
Groundbirch East from BC to Alberta averaging lower (0.3 bcf/d vs 0.5 bcf/d) since Feb 1st as more gas flows in on NMML, tightening cash spreads between station 2 and AECO. The weather is expected to warmer than normal over 6-10 and 8-14.
Daily Gas Market Fundamentals (BMO Forecast)
Natural Gas Commentary
Cash Fixed Price Liquidations (NGX)
NYMEX Natural Gas (USD/MMBTU) AECO Basis (USD/MMBTU)
$0.030
$0.016
$0.004
AECO (CAD/GJ)
Change
$0.031
$0.042
$0.034
$0.037
97.95
96.96
28.10
23.40
92.04
0.12
4.80
Daily Market Summary ReportCommodities | Fixed Income, Currencies and Commodities
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US Gas Production Bcf/d (Bloomberg) US Storage Bcf (Bloomberg)
GFS Ensembel L48 Forecast L48 Res/Comm Forecast Baker Hughes Rig Count
60
65
70
75
80
85
90
95
100
J F M A M J J A S O N D
201 8 201 9 202 0 BM O Fo recast
0
500
100 0
150 0
200 0
250 0
300 0
350 0
400 0
450 0
J F M A M J J A S O N D
5yr Ran ge 5 Yr Average 201 8 201 9 202 0
Price Change LLS Midland Edm SW WCS Edm C5 Price Change Price Change Price Change Spread
Prompt Future $46.78 -$0.40 ($2.65) ($14.25) ($2.12) $51.13 -$0.730 $1.5273 $0.00
Calendar Apr $47.00 -$0.37 $3.01 $1.32 $51.25 -$0.513 $63.01 -$0.38 $1.5273 $0.00 $1.1966
Apr20-Jun20 $47.13 -$0.33 $2.92 $1.28 ($3.27) ($14.75) ($3.74) $51.31 -$0.40 $63.19 -$0.32 $1.5295 $0.00 $1.2000
Zero-Cost Collar $40.00/$52.88 $45.00/$56.51 $58.00/$66.92 $1.304/$1.750
Zero-Cost Collar $38.00/$54.41 $40.00/$60.27 $56.00/$68.39 $1.304/$1.750
Apr20-Dec20 $47.37 -$0.22 $2.84 $1.28 ($5.29) ($15.83) ($4.54) $51.64 -$0.24 $63.53 -$0.18 $1.5587 $0.00 $1.1931
Zero-Cost Collar $43.00/$50.99 $50.00/$52.81 $56.00/$69.31 $1.123/$2.000
Zero-Cost 3-Way $40/$46/$51.96 $1.399/$1.75/$2.00
Apr20-Oct20 $47.29 -$0.25 $2.87 $1.27 ($4.63) ($15.24) ($4.46) $51.53 -$0.28 $63.42 -$0.22 $1.5734 $0.00 $1.1896
Jul20-Dec20 $47.49 -$0.17 $2.80 $1.28 ($6.30) ($16.37) ($4.94) $51.80 -$0.16 $63.70 -$0.11 $1.5569 $0.00 $1.2005
Jul20-Sep20 $47.38 -$0.20 $2.84 $1.26 ($5.17) ($15.22) ($5.14) $51.63 -$0.21 $63.54 -$0.16 $1.5898 $0.00 $1.1786
Oct20-Dec20 $47.59 -$0.13 $2.75 $1.79 ($7.43) ($17.52) ($4.75) $51.97 -$0.12 $63.87 -$0.07 $1.6302 $0.01 $1.2173
Jan21-Dec21 $48.04 -$0.08 $2.58 $1.34 ($7.50) ($18.66) ($5.00) $52.69 -$0.04 $64.57 $0.00
Apr20 Apr20-Jun20 Apr20-Dec20 Spot Spot Change Storage (MMBbls) Current W/W Change Last Year 5 Yr. Avg.
USGC Diesel $1.4739 $1.4795 $1.5018 Gold $1,642 CAD/USD $1.3427 $0.0088 Crude Ex SPR 444.1 0.2% 453 463
USGC Jet $1.4123 $1.4170 $1.4512 Silv er $17 USD/EUR $1.1136 -$0.0037 Crude at Cushing 37.2 -5.0% 48 44
NYMEX RBOB $1.5392 $1.5266 $1.4320 Platinum $876 USD/GBP $1.2872 $0.0061 Mogas 252.0 -1.7% 251 251
NYMEX 3:2:1 Crack $0.4161 $0.4054 $0.3464 Palladium $2,468 1 Mo BA's 1.5100 -0.2325 Distillates 134.5 -2.9% 136 142
Purity Ethane $0.1475 $0.1450 $0.1554 3 Mo 3 Mo BA's 1.5025 -0.2300
Conway Propane $0.3625 $0.3642 $0.4019 Aluminium $1,726 6 Mo BA's 1.4900 -0.2338 Production (MMBbls) Current Mo/Mo Change Last Year 5 Yr. Avg.
Mt Bel Propane Non-LST $0.4100 $0.4133 $0.4406 Copper $5,684 CAD Prime 3.9500 0.0000 OPEC 27.9 -2.70% 29.8 30.8
Mt Bel N.Butane Non-LST $0.5425 $0.5400 $0.5579 Zinc $1,982 US 3 Mo Libor 1.3143 -0.1485 Russia 11.3 0.33% 11.4 11.2
Mt Bel I.Butane Non-LST $0.5825 $0.5733 $0.5835 Nickle $12,680 US 13.1 1.55% 12.1 11.1
Mt Bel C5 Non-LST $0.9475 $0.9413 $0.9335 Lead $1,820 Rest of World 48.1 -0.17% 47.0 45.9
Crude, Products and Metals Pricing
The wild ride continues, with virus, OPEC, and inventory news all playing a role today. First OPEC: the Saudis were seeking a cut of more than 1MMbpd, some say 1.5MMbpd even, and other OPEC members seemed to be fall ing
in l ine, but Russia is no mood to participate it seems which would leave Saudi Arabia on its own for the most part. A couple of more days and we’ll know if Russia capitulates at the last minute. Regarding the virus, U.S. fatalities
are now at 11. For perspective, the CDC estimate for flu-related deaths in the U.S. just this season is 18,000. Thank goodness the media doesn’t report on the flu the way they do coronavirus or grocery stores and businesses would
be empty. Not to make light of the highly contagious coronavirus, but perspective is helpful and often necessary. Anyway, South Korea seems to be ground zero now, not China. Finally, crude oil inventory numbers in the U.S. were
mixed between bullish and bearish. Cushing stocks declined nearly 2MM barrels, but overall stocks gained nearly 800k barrels, with a gain of nearly 3.5MM barrels in PADD3. Gasoline stocks declined a whopping 4.34MM barrels
and disti l late a similar 4MM barrels, for a total products decline of over 8MM barrels. Bullish, no? However, refinery runs were lower by 312Kbpd on util ization of 86.9%. So, in summary, quite the mixed bag of news today.
Petroleum Commentary
NYMEX WTI (USD/BBL)
March 4, 2020
NYH ULSD (USD/GAL) Diesel CAD WTI (CAD/BBL)ICE Brent (USD/BBL)Oil Spread Differential (USD/BBL)
Other Refined Products & NGLs (USD/GAL)
Crude Market Fundamentals
Metals Exchange & Lending Rates Crude Storage & Production (Bloomberg)
Daily Market Summary ReportCommodities | Fixed Income, Currencies and Commodities
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Annual Supply & Demand Balance (MMbbls), North American Crude Storage (MMbbls) US Refinery Utilization EIA
Pricing Differentials (USD/bbl)NYMEX Futures CurveUS Crude Imports (MMbpd), EIA
-$4
-$2
$0
$2
$4
$6
$8
$35
$39
$43
$47
$51
$55
$59
$63
$67
$71
$75
$79
Apr-20 Oct-22 Apr-25 Oct-27
Delta Today 1 Mo Ago
0
10
20
30
40
50
60
70
80
90
Jan-17 May-17 Sep-17 Jan-18 May-18 Sep-18 Jan-19 May-19 Sep-19 Jan-20
WTI-WCS BRENT-WTI Brent WTI WCS
0
50
100
150
200
250
300
350
400
450
500
02/08/19 02/07/20 02/15/19 02/14/20 02/22/19 02/21/20 03/01/19 02/28/20
Tota
l Bui
ld o
f 784
Cush
ing
Draw
of -
1971
Cushing Max
0
2
4
6
8
10US IMPORTS CAD Imports CAD Heavy Imports
*Heavy imports reported on a lagging basis
60%
65%
70%
75%
80%
85%
90%
95%
100%
105%
Jan-17 May-17 Sep-17 Jan-18 May-18 Sep-18 Jan-19 May-19 Sep-19 Jan-20
US TOTAL PAD III PAD IITotal Crude Last Year
Cushing Last Year
Total Crude Last Year
Cushing Last Year
0.79
0.57
-0.44
-1.48
0.00
-0.68
0.03
-0.56
0.03
-0.91
0.20
1.14
0.04
-0.84
0.86
-0.06
0.23
-2.0 0
-1.5 0
-1.0 0
-0.5 0
0.00
0.50
1.00
1.50
2004 2007 2010 2013 2016 2019
Crude Surplus
Crude Shortage