National Association of Publicly Traded Partnerships May ...€¦ · 2012 Master Limited...
Transcript of National Association of Publicly Traded Partnerships May ...€¦ · 2012 Master Limited...
2012 Master Limited Partnership Conference National Association of Publicly Traded Partnerships
May 23, 2012
Forward Looking Statements
This presentation contains forward looking statements within the meaning of the
federal securities laws. Forward looking statements are not guarantees of performance.
They involve risks, uncertainties and assumptions. The future results of Crosstex
Energy, L.P. and its affiliates (collectively known as “Crosstex”) may differ materially
from those expressed in the forward-looking statements contained throughout this
presentation and in documents filed with the SEC. Many of the factors that will
determine these results are beyond Crosstex’s ability to control or predict. These
statements are necessarily based upon various assumptions involving judgments with
respect to the future, including, among others, the ability to achieve synergies and
revenue growth; national, international, regional and local economic, competitive and
regulatory conditions and developments; technological developments; capital markets
conditions; inflation rates; interest rates; the political and economic stability of oil
producing nations; energy markets; weather conditions; business and regulatory or
legal decisions; the pace of deregulation of retail natural gas and electricity; the timing
and success of business development efforts; and other uncertainties. You are cautioned
not to put undue reliance on any forward looking statement. Crosstex has no obligation
to publicly update or revise any forward looking statement, whether as a result of new
information, future events or otherwise. 2
Crosstex GP, LLC
Public/Other Shareholders
100%
Public Unitholders
56%
• 2% GP Interest
• 100% IDRs
Crosstex Energy, Inc. (NASDAQ: XTXI)
Directors / Executive Officers
87% 13%
2%
22%
Crosstex Energy, L.P. (NASDAQ: XTEX)
20%
GSO Crosstex
Holdings
Corporate Structure
3
• $635 million Revolving Credit Facility
• 8.875% Senior Notes due 2018
• 7.125% Senior Notes due 2022*
Crosstex Energy
Services, LP.
All Assets
and Operations
* 7.125% Senior Notes contingent upon closing of Clearfield acquisition
• Over 2,800 miles of natural gas gathering and transmission pipeline
• 10 natural gas processing plants
• 4 fractionators
• Over 470 miles of NGL pipeline
• 2.4 MM barrels of NGL cavern storage
• Crude terminals – S. La.
4
Services Provided
5
Strategically Located Assets
LIG
• ~2,100 miles of pipeline
• 2 processing plants
• 2 treating plants
PNGL
• ~440 miles of NGL pipeline
• 4 processing plants
• 3 fractionation facilities
North Texas
• ~840 miles of pipeline
• 3 processing plants
• 2 treating plants Permian Basin – Apache JV
• 50 MMcf/d cryogenic processing
plant
• Mesquite fractionator and rail
terminal
Crude
• Crude truck, rail and barge transloading facilities:
− Riverside: 4,500 Bbl/d existing + ~10,000 Bbl/d under construction
− Eunice: 3,000 Bbl/d existing
Cajun Sibon
• ~130-mile NGL pipeline
from Mt. Belvieu to
expanded fractionation
assets in LA
Clearfield - Utica
• ~200 miles of crude &
condensate pipeline
• Truck, rail, barge, and
brine disposal facilities
Eagle Ford
• Strategic investment in Howard Energy
• ~450 miles of pipeline
• Pipeline and plant construction operations
Truck Unloading Station
Brine Disposal Well
Barge Terminal
Rail Terminal
Storage
Processing Plant
Fractionator
Recent Accomplishments
* Debt issuance contingent upon closing of Clearfield acquisition 6
Our strategy is to:
• Maximize earnings and growth of existing businesses
• Grow business to enhance scale and diversification and to create value
Continue focus on new core businesses to enhance diversification and scale:
• Increase NGL business
• Grow Crude, Logistics and Salt Water Disposal business
• Develop GP&T business in rich gas areas
Near Term Strategic Plan
7
Committed to Diversified Growth
8
Crosstex continues to effectively execute its growth and
expansion strategy:
Investments and Acquisitions
Clearfield Energy, Inc. Acquisition $210
Howard Energy Partners - Meritage Investment 52
Sub-total Investments and Acquisitions $262
Organic Growth and Expansion
Cajon Sabon Phase I $230
Clearfield Energy / Utica Shale Expansion - Post Acquisition 50
Permian Basin 29
PNGL Crude Terminals 21
Other Organic Growth 30
Sub-total Organic Growth And Expansion $360
Total Growth $622
Projected Capital Spend(amounts in millions)
Clearfield Energy, Inc. Overview
9
Transaction Overview
10
The Transaction:
Agreement to acquire privately held Clearfield Energy, Inc. for $210 million
9X EBITDA multiple, expected to move to a 5X EBITDA multiple within three years; $50 million
additional capital investment
Anticipated closing date – July 2012
Financing through a combination of debt and equity
The Company:
Clearfield Energy, Inc:
125 years of history in Ohio; formerly (prior to 1983) Buckeye Pipeline’s Mackburg Division, created
in 1886
Fee-based crude and condensate services in Ohio, West Virginia, and Kentucky
− Pipeline, rail, barge, and trucks
Fee-based brine collection and disposal services in Ohio and West Virginia
− Four wholly owned and two joint venture disposal wells
Handles 30% of all oil production in Ohio and Kentucky; 55% in West Virginia,
− Majority of new Utica Shale oil production
Current Volumes ~10,000 Bbl/d of crude/condensate and ~5,700 Bbl/d of brine
Revenue mix: 75% crude/condensate and 25% brine
Clearfield Energy, Inc. Asset Overview
11
Assets include:
- 4,500 Bbl/hr barge
terminal on the Ohio
River
- 20 car-28,000 Bbl/d
(expanding to 40 car-
56,000 Bbl/d by end of
2012) rail loading terminal
on the Ohio Central
Railroad
- ~120 miles of 8” pipeline
in Ohio (Current capacity
10,000Bbl/d)
- ~80 miles of 6” pipeline in
West Virginia (Current
capacity 7,000Bbl/d)
- Over 2,500 miles of
unused ROW
- ~100,000 Bbls of above
ground storage
- 4 wholly owned brine
disposal wells, 2 joint
venture disposal wells, 1
additional well currently
being completed and 1
being permitted
- Extensive fleet of trucks
(Current capacity 35,000
Bbl/d)
Source: Ohio Department of Natural Resources
Truck Unloading Station
Brine Disposal Well
Barge Terminal
Rail Terminal
Existing Pipeline
Business Overview by Asset
NTX: Strategically Positioned in the Barnett Shale
Well Positioned Assets (current capacity) :
• NTPL – 375 MMcf/d
• NTX Gathering Assets – 1 Bcf/d +
• Azle plant – 50 MMcf/d
• Goforth plant – 30 MMcf/d
• Silvercreek plant – 200 MMcf/d
• Compression HP – 191,652
2011Segment Cash Flow
LTM 3/31/2012 Throughput :
• NTX – Gathering – 803,000 MMBtu/d
• NTX – Transmission – 352,000 MMBtu/d
• NTX – Processing – 275,000 MMBtu/d
Note: Segment Cash Flow is a non-GAAP financial measure. See Appendix for reconciliation to Operating Income (loss) 13
LIG: Strategically Positioned Assets
2011Segment Cash Flow
Note: Segment Cash Flow is a non-GAAP financial measure. See Appendix for reconciliation to Operating Income (loss)
Well Positioned Assets (current
capacity):
• LIG Pipeline – 1Bcf/d+
• LIG Red River 24” Expansion – 465 MMcf/d
• Plaquemine Plant – 225 MMcf/d; 10,000 Bbls/d Fractionator
• Gibson Plant – 110 MMcf/d
LTM 3/31/2012 Throughput:
• LIG – Gathering / Transmission 899,000 MMBtu/d
• LIG – Processing – 248,000 MMBtu/d
14
PNGL: Strategically Positioned Assets
Well Positioned Assets (current capacity):
• Eunice – 750 MMcf/d; 15,000 Bbls/d
• Pelican – 600 MMcf/d
• Sabine – 300 MMcf/d
• Blue Water – 525 MMcf/d
• Riverside – 27,000 Bbls/d
• Napoleonville Storage – 2.4 MMBbls
2011Segment Cash Flow
Note: Segment Cash Flow is a non-GAAP financial measure. See Appendix for reconciliation to Operating Income (loss)
LTM 3/31/2012 Throughput:
• Processing – 824,000 MMBtu/d
• NGL Fractionation – 1,121,000 gal/d
15
Cajun Sibon Phase I
• Project includes building ~130-mile NGL pipeline from Mt. Belvieu and expanding fractionation assets in LA
• Estimated in service date in first half of 2013 • Estimated Capex of $230MM excluding raw make storage
16
Permian Basin Expansion
• Joint venture with Apache: 50 MMcf/d cryogenic facility; 50% owned – Operated by Crosstex
• Mesquite fractionator and rail terminal: 100% owned - Creates space for Apache NGLs
17
Eagle Ford Expansion
• Strategic investment in Howard
Energy Partners to pursue
opportunities in the Eagle Ford Shale
• Completed a 30-mile, 12-inch
diameter pipeline expansion for rich
gas header since initial acquisition
• Acquired Meritage assets in April
2012
18
Financial Overview
Current Financial Focus
• Maintaining strong liquidity position for flexibility with no near term debt maturities
• Maintaining conservative capital structure and leverage ratios
– Match distributions with more reliable cash flows
– Reinvest excess coverage from less sustainable cash flows
– Funded over $400 million of 2012 growth capital through recent debt and equity issuance*
• Improving cash flows by:
– Investing in high-return projects
– Improving efficiencies of existing assets
20
4.23x
4.08x3.96x 3.90x 3.96x 3.92x
4.07x
1.34x
1.60x1.57x 1.53x
1.19x
1.41x1.52x
$0.00
$0.05
$0.10
$0.15
$0.20
$0.25
$0.30
$0.35
1.00x
1.50x
2.00x
2.50x
3.00x
3.50x
4.00x
4.50x
3Q 2010 4Q 2010 1Q 2011 2Q 2011 3Q 2011 4Q 2011 1Q 2012
Quarterly Leverage and Distribution
Dist/unit Leverage Dist. Coverage
* Debt contingent upon closing of Clearfield acquisition
58%66%
62%57% 54%
10%
12%14%
13% 19%
15%
9% 13%19%
17%
17%13% 11% 11% 10%
0%
10%
20%
30%
40%
50%
60%
70%
80%
90%
100%
2008* 2009 2010 2011 2012**
Gathering & Transmission Fee Based Processing & Fractionation
Processing Margin Percent of Liquids
Fee Based Focus
* 2008 excludes discontinued operations ** 2012 represents midpoint of guidance
~ 70% Fee-based business
21
Solid Performance in All Core Areas
Note: Segment Cash Flow is a non-GAAP financial measure. See Appendix for reconciliation to Operating Income (loss) * 2012 represents mid-point of guidance without adjustment for the Clearfield acquisition ** Cash flows from Permian assets are included in the North Texas and PNGL segment amounts
CAGR (2008 – 2012) for total segment cash flows of 9.9%
22
Years Ended December 31,
Segment Cash Flow 2008 2009 2010 2011 2012 *
(Amounts in Millions)
North Texas ** 103$ 113$ 114$ 126$ 126$
LIG 82 80 82 95 89
PNGL ** 12 21 38 51 72
Total Asset Segments 197$ 214$ 235$ 272$ 287$
Appendix
2012/2013 Hedge Positions
24
Hedged Volume as a % of Hedgeable Volume
Q2 Q3 Q4 Q1 Q2 Q3 Q4
POL
Total VAR Volumes 4.82 6.02 5.78 5.46 5.32 5.20 5.03
Total Hedgeable Volumes 2.97 4.07 3.57 3.40 3.29 3.20 3.05
Total Hedged Volumes 2.61 1.66 1.92 1.95 1.69 1.35 1.53
Hedged Percentage 88% 41% 54% 57% 51% 42% 50%
Proc Margin
Total VAR Volumes 33.67 38.53 38.50 37.56 38.09 38.64 38.67
Total Hedgeable Volumes 6.54 6.63 6.64 5.94 6.03 6.12 6.14
Total Hedged Volumes 4.51 2.77 2.02 1.31 1.21 0.77 0.99
Hedged Percentage 69% 42% 30% 22% 20% 13% 16%
2012 2013
(Volumes in MM gallons)
Processing Sensitivities Matrix Total Year 2012
Note: All amounts in millions except prices & ratios and include hedge impacts. 25
Natural Gas Price Natural Gas Price
$2.00 $2.50 $3.00 $3.50 $4.00 $2.00 $2.50 $3.00 $3.50 $4.00
300% $0.510 $0.637 $0.765 $0.892 $1.020 300% $52.0 $59.0 $66.1 $73.1 $80.1
335% $0.569 $0.712 $0.854 $0.996 $1.138 335% $57.5 $65.9 $74.3 $82.7 $91.1
410% $0.697 $0.871 $1.045 $1.219 $1.393 410% $69.2 $80.6 $91.9 $103.3 $114.6
485% $0.824 $1.030 $1.236 $1.442 $1.648 485% $81.0 $95.3 $109.6 $123.8 $138.1
550% $0.935 $1.168 $1.402 $1.636 $1.869 550% $91.2 $108.0 $124.8 $141.7 $158.5
$2.00 $2.50 $3.00 $3.50 $4.00 $2.00 $2.50 $3.00 $3.50 $4.00
300% $21.5 $23.9 $26.4 $28.9 $31.4 300% $30.5 $35.1 $39.6 $44.2 $48.8
335% $22.6 $25.4 $28.2 $30.9 $33.7 335% $34.9 $40.5 $46.1 $51.8 $57.4
410% $25.1 $28.5 $31.9 $35.3 $38.7 410% $44.1 $52.1 $60.0 $68.0 $75.9
485% $27.6 $31.7 $35.7 $39.7 $43.7 485% $53.4 $63.6 $73.9 $84.2 $94.4
550% $29.8 $34.4 $38.9 $43.5 $48.0 550% $61.4 $73.7 $85.9 $98.2 $110.5
Gross Margin from Total POL Contracts
Natural Gas Price Natural Gas PriceNGL to
Gas Ratio
Gross Margin from Total POL & PM ContractsNGL Basket Price Per Gallon
NGL to
Gas Ratio
NGL to
Gas Ratio
Gross Margin from Total PM Contracts
NGL to
Gas Ratio
Approximates Year 2012 Low Guidance
Approximates Year 2012 Midpoint of Guidance
Approximates Year 2012 High Guidance
26
Reconciliation: Segment Cash Flow to Operating Income (Loss)
* Other includes LOC fees, Stock Based Compensation and gains or losses on derivatives 26
(Amounts in Millions) 2007 2008 2009 2010 2011 2012 *
Total Asset Team Segment Cash Flow 176$ 197$ 214$ 235$ 272$ 287$
Shared Services (11) (15) (14) (13) (16) (18)
Other ** (3) (7) (3) 11 8 1
Asset Team Segment Profits 161$ 176$ 197$ 233$ 264$ 270$
Corporate Segment Profits 8 6 3 - - -
Segment Profits 169$ 182$ 201$ 233$ 264$ 270$
General and administrative expenses (60) (69) (60) (48) (53) (59)
Gain (loss) on derivatives 4 9 3 (9) (8) -
Gain on sale of property 1 1 1 14 (0) -
Depreciation, amortization and impairment (83) (137) (122) (113) (125) (126)
Operating income (loss) 31$ (14)$ 23$ 77$ 77$ 86$
Years Ended December 31,
* 2012 Represents mid-point of guidance without adjustment for the Clearfield acquisition
* * Other includes the impact of LOC fees, Gain (Loss) on derivatives and stock-based compensation allocated to operations
* 2012 Represents mid-point of guidance without adjustment for the Clearfield acquisition
* * Other includes the impact of LOC fees, Gain (Loss) on derivatives and stock-based compensation allocated to operations