North American Power Credit Organization - RMG Financial...Base Export Capacity
Transcript of North American Power Credit Organization - RMG Financial...Base Export Capacity
North American Power Credit Organization The Changing Landscape in the Midstream Michael A. Tribolet Managing Director, Energy Group
Las Vegas, Nevada
January 16, 2014
© 2014 Wells Fargo Bank, N.A. All rights reserved.
1
Drilling technology
Wildcatting versus manufacturing
Rig technology
Faster drilling completion times
Pad drilling
Directional drilling and fracing
Longer horizontal well bores
More perforations per distance
Better proppants and chemicals
2
U.S. hydrocarbon production
-
10,000,000
20,000,000
30,000,000
40,000,000
50,000,000
60,000,000
70,000,000
80,000,000
-
1,000,000
2,000,000
3,000,000
4,000,000
5,000,000
6,000,000
7,000,000
8,000,000Ja
n-07
Jul-
07Ja
n-08
Jul-
08Ja
n-09
Jul-
09Ja
n-10
Jul-
10Ja
n-11
Jul-
11Ja
n-12
Jul-
12Ja
n-13
Jul-
13
Monthly Production
Total Oil
Total Natural Gas
Bbl/day Mcf/day
Source: Energy Information Administration
3
Basins
Bakken
Niobrara
Eagle Ford
Permian Haynesville
Marcellus
Source: Energy Information Administration
4
Source: Energy Information Administration
-
2,000,000
4,000,000
6,000,000
8,000,000
10,000,000
12,000,000
14,000,000
16,000,000
Jan-
07
Jun-
07
Nov
-07
Apr
-08
Sep
-08
Feb-
09
Jul-
09
Dec
-09
May
-10
Oct
-10
Mar
-11
Aug
-11
Jan-
12
Jun-
12
Nov
-12
Apr
-13
Sep
-13
Mcf
per
day
Monthly Natural Gas Production
Bakken
Eagle Ford
Haynesville
Marcellus
Niobrara
Permian
5
-
200,000
400,000
600,000
800,000
1,000,000
1,200,000
1,400,000
1,600,000
Jan-
07
Jun-
07
Nov
-07
Apr
-08
Sep
-08
Feb-
09
Jul-
09
Dec
-09
May
-10
Oct
-10
Mar
-11
Aug
-11
Jan-
12
Jun-
12
Nov
-12
Apr
-13
Sep
-13
Bar
rels
per
Day
Monthly Oil Production
Bakken
Eagle Ford
Haynesville
Marcellus
Niobrara
Permian
Source: Energy Information Administration
6
Bakken
-
100
200
300
400
500
600Ja
n-07
May
-07
Sep
-07
Jan-
08M
ay-0
8Sep
-08
Jan-
09M
ay-0
9Sep
-09
Jan-
10M
ay-1
0Sep
-10
Jan-
11M
ay-1
1Sep
-11
Jan-
12M
ay-1
2Sep
-12
Jan-
13M
ay-1
3Sep
-13
New well production of oil (Bbl/day)
Production per rig
Rig count
Source: Energy Information Administration
7
Bakken
Source: Energy Information Administration
-
50
100
150
200
250
300
350
400
450
500
Jan-
07M
ay-0
7Sep
-07
Jan-
08M
ay-0
8Sep
-08
Jan-
09M
ay-0
9Sep
-09
Jan-
10M
ay-1
0Sep
-10
Jan-
11M
ay-1
1Sep
-11
Jan-
12M
ay-1
2Sep
-12
Jan-
13M
ay-1
3Sep
-13
New well production of natural gas (Mcf/day)
Production per rig
Rig count
8
Eagle Ford
Source: Energy Information Administration
-
50
100
150
200
250
300
350
400
450
Jan-
07M
ay-0
7Se
p-07
Jan-
08M
ay-0
8Se
p-08
Jan-
09M
ay-0
9Se
p-09
Jan-
10M
ay-1
0Se
p-10
Jan-
11M
ay-1
1Se
p-11
Jan-
12M
ay-1
2Se
p-12
Jan-
13M
ay-1
3Se
p-13
New well production of oil (Bbl/day)
Production per rig
Rig count
9
Marcellus
Source: Energy Information Administration
-
1,000
2,000
3,000
4,000
5,000
6,000
7,000
Jan-
07Apr
-07
Jul-
07O
ct-0
7Ja
n-08
Apr
-08
Jul-
08O
ct-0
8Ja
n-09
Apr
-09
Jul-
09O
ct-0
9Ja
n-10
Apr
-10
Jul-
10O
ct-1
0Ja
n-11
Apr
-11
Jul-
11O
ct-1
1Ja
n-12
Apr
-12
Jul-
12O
ct-1
2Ja
n-13
Apr
-13
Jul-
13O
ct-1
3
New well production of natural gas (Mcf/day)
Production per rig
Rig count
10
New versus legacy decline
Source: Energy Information Administration
-10.0%
-5.0%
0.0%
5.0%
10.0%
15.0%
20.0%
Mar
-07
Jun-
07
Sep
-07
Dec
-07
Mar
-08
Jun-
08
Sep
-08
Dec
-08
Mar
-09
Jun-
09
Sep
-09
Dec
-09
Mar
-10
Jun-
10
Sep
-10
Dec
-10
Mar
-11
Jun-
11
Sep
-11
Dec
-11
Mar
-12
Jun-
12
Sep
-12
Dec
-12
Mar
-13
Jun-
13
Sep
-13
Monthly growth in Bakken oil production
Legacy production
New production
Total production
11
New versus legacy decline
Source: Energy Information Administration
-8.0%
-6.0%
-4.0%
-2.0%
0.0%
2.0%
4.0%
6.0%
8.0%
10.0%
12.0%
Feb-
08Apr
-08
Jun-
08Aug
-08
Oct
-08
Dec
-08
Feb-
09Apr
-09
Jun-
09Aug
-09
Oct
-09
Dec
-09
Feb-
10Apr
-10
Jun-
10Aug
-10
Oct
-10
Dec
-10
Feb-
11Apr
-11
Jun-
11Aug
-11
Oct
-11
Dec
-11
Feb-
12Apr
-12
Jun-
12Aug
-12
Oct
-12
Dec
-12
Feb-
13Apr
-13
Jun-
13Aug
-13
Oct
-13
TTM average monthly growth in Bakken oil production
Legacy production
New production
Total production
12
Crude oil and natural gas price
$-
$5.00
$10.00
$15.00
$20.00
$25.00
$30.00
$-
$20.00
$40.00
$60.00
$80.00
$100.00
$120.00
$140.00
$160.00
$180.00
Crude Oil
Natural Gas
13
Crude oil to natural gas price
-
10.0
20.0
30.0
40.0
50.0
60.0
Jan-04 Jan-05 Jan-06 Jan-07 Jan-08 Jan-09 Jan-10 Jan-11 Jan-12 Jan-13 Jan-14
Crude Oil / Natural Gas
14
Crude oil to natural gas price
-
5.0
10.0
15.0
20.0
25.0
Feb-
14Apr
-14
Jun-
14Aug
-14
Oct
-14
Dec
-14
Feb-
15Apr
-15
Jun-
15Aug
-15
Oct
-15
Dec
-15
Feb-
16Apr
-16
Jun-
16Aug
-16
Oct
-16
Dec
-16
Feb-
17Apr
-17
Jun-
17Aug
-17
Oct
-17
Dec
-17
Feb-
18Apr
-18
Jun-
18Aug
-18
Oct
-18
Dec
-18
Feb-
19Apr
-19
Jun-
19Aug
-19
Oct
-19
Dec
-19
Crude Oil / Natural Gas
15
Processing
Pipeline quality natural gas must be 1,035 Btu per cubic foot, plus or minus 5%
Remove water
Remove hydrogen sulfide
Remove carbon dioxide
16
Natural gas liquids – The “C’s”
Approx. Gross BTU’s per cubic foot
Methane – CH4 1,010
Ethane - C2H6 1,760
Propane – C3H8 2,520
Normal Butane – C4H10
3,270
Isobutane – C4H10 3,260
Pentanes – C5H12 4,010
17
Ethane
Ethane is 1% to 6% of the volume in natural gas
Primarily used in the chemical industry in the production of ethylene
Ethylene is most used as a polymer in the manufacture of plastic packaging
In periods of oversupply ethane trades at its heat value and is then highly correlated to natural gas prices.
Instead of ethane extraction, ethane rejection occurs in this oversupply when it is left in the natural gas stream to increase the blended btu per cubic foot
18
Ethane to natural gas differential
($4.00)
($2.00)
$0.00
$2.00
$4.00
$6.00
$8.00
$10.00
$12.00
$14.00
Ethane minus natural gas (per mmbtu)
19
Ethane supply
Source: Wells Fargo Securities, LLC estimates and Energy Information Administration
Build up of Ethane Supply2013E 2014E 2015E 2016E 2017E 2018E
Capacity to produce as of Dec 2012 1,030 1,030 1,030 1,030 1,030 1,030
Mont Belvieu Fractionation Expansions 185 386 396 396 396 396 Conway Fractionation Expansion 19 26 26 26 26 26 Appalachia Fractionation Expansion 53 273 367 367 367 367
Total Potential US Ethane Supply 1,287 1,714 1,818 1,818 1,818 1,818
Capacity to Consume as of Dec 2012 1,050 1,050 1,050 1,050 1,050 1,050
Gulf Coast Conversion Projects 31 80 83 118 118 118 Gulf Coast Ethylene Expansions 30 67 98 98 98 98 Gulf Coast Crackers - - - 78 353 423 Other USA 1 14 14 14 14 89 Ethane Export Projects 36 95 135 135 135 135
Total Potential US Ethane Demand 1,149 1,306 1,380 1,493 1,768 1,914
Ethane Over / (Under) Supply 138 408 438 325 50 (96)
Fig u r es m a y n ot a dd du e to r ou n din g
Thousand barrels per day
20
Propane supply / demand
Source: EIA, Hodson Report, CMAI, and Wells Fargo Securities, LLC estimates
21
Propane price differentials
Source: Wells Fargo Securities, LLC, CMAI, Waterborne
22
Propane exports encouraged by global price differentials
0
100
200
300
400
500
600
700
800
900
2009 2010 2011 2012 2013 2014 2015 2016 2017
Tota
l Ex
por
t C
apac
ity
(MB
BLS
/D)
EPD Export Terminal Capacity NGLS Export Terminal Capacity Vitol Group Sunoco Logistics
Est. in Service 2009 2010 2011 2012 2013 2014 2015 2016 2017
EPD Export Terminal CapacityBase Export Capacity <Q1'09 132 132 132 132 132 132 132 132 132Base De-Bottleneck Q3'12 0 0 0 2 3 3 3 3 3Expansion I Q1'13 0 0 0 0 120 153 153 153 153Exp. De-bottleneck Q3'13 0 0 0 0 24 48 48 48 48
NGLS Export Terminal CapacityBase Export Capacity <Q1'09 33 33 33 33 33 33 33 33 33Base De-Bottleneck Q1'12 0 0 0 16 16 16 16 16 16Expansion I Q3'13 0 0 0 0 36 72 72 72 72Expansion II Q3'14 0 0 0 0 0 36 72 72 72
Vitol GroupCoastal Caverns (Vitol) Q4'14 0 0 0 0 0 9 37 37 37
Sunoco LogisticsBase Export Capacity Q2'15 0 0 0 0 0 0 26 35 35Mariner South (SXL) Q1'15 0 0 0 0 0 0 200 200 200
Total LPG Export Capacity 165 165 165 183 364 502 792 801 801
*Company terminal capacities are based on an assumed available daily operating rate of 80%
Source: Wells Fargo Securities, LLC, CMAI, BPN’s Weekly Propane Newsletter
23
Butane Supply / Demand Model
Butane fundamentals
Source: EIA, Jacobs Consultancy; The Hodson Report, CMAI, and Wells Fargo Securities, LLC estimates
24
Processing contracts
Fee-based: The processor receives a fee based on the volumes of gas it processes. Volume sensitive, but less so to commodity price. When NGL prices are low, producers may leave NGL in the gas stream to meet pipeline quality natural gas requirements.
25
Processing contracts
Keep-whole: The processor commits to accept natural gas from the producer and the processor retains ownership of the NGLs, but gives the producer processed natural gas with the same overall heat content.
For example, if the producer sends 10 mmbtu’s of unprocessed gas, of which 2 mmbtu’s are NGL’s and 8 mmbtu’s are pure natural gas, the processor would return 10 mmbtu’s of natural gas.
If NGL’s are higher in price relative to natural gas, keep-whole contracts give the processor larger processing margins.
26
Processing contracts
Percent of proceeds (POP): The producer and processor agree to split the value of the natural gas and the NGL’s on a set percentage.
For example, the producer may agree to accept 85% of the value of the natural gas and NGL’s, while the processor is paid 15% for processing the gas.
The processor benefits from high natural gas prices and NGL prices, as opposed to NGL’s being high in price relative to natural gas.
27
LNG exports
Source: Bentek (11/6/2013)
28
US natural gas exports to Mexico
0.00
0.50
1.00
1.50
2.00
2.50
Apr-00 Oct-01 Apr-03 Oct-04 Apr-06 Oct-07 Apr-09 Oct-10 Apr-12
Nat
ural
Gas
Exp
orts
to
Mex
ico
(BCF/
D) 110% Growth since 2005
Source: Energy Information Administration
29
Questions