BP MIDSTREAM PARTNERS 4Q & FULL YEAR 2018 RESULTS
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BP MIDSTREAM PARTNERS
BP Midstream Partners 4Q and full year 2018
Results
February 28, 2019
BP MAD DOG Offshore deepwater Gulf of Mexico
BP Midstream Partners 4Q and full year 2018 Results February 28, - - PowerPoint PPT Presentation
BP MIDSTREAM PARTNERS BP Midstream Partners 4Q and full year 2018 Results February 28, 2019 BP MAD DOG 1 BP MIDSTREAM PARTNERS 4Q & FULL YEAR 2018 RESULTS Offshore deepwater Gulf of Mexico Cautionary statement BP MIDSTREAM PARTNERS
BP MIDSTREAM PARTNERS 4Q & FULL YEAR 2018 RESULTS
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BP MIDSTREAM PARTNERS
BP MAD DOG Offshore deepwater Gulf of Mexico
BP MIDSTREAM PARTNERS 4Q & FULL YEAR 2018 RESULTS
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BP MIDSTREAM PARTNERS
FORWARD-LOOKING STATEMENTS This presentation includes various “forward looking statements” within the meaning of the Securities Act of 1933, as amended, and the Securities Exchange Act of 1934, as amended. All statements, other than statements of historical fact, regarding BP Midstream Partners LP’s (“BP Midstream,” “we,” “us” or “our”) strategy, future operations, financial position, estimated revenues and losses, projected costs, prospects, plans and objectives of management are forward-looking
statements contain such identifying words. These forward-looking statements are based on BP Midstream's current expectations and assumptions about future events and are based on currently available information as to the outcome and timing of future events. In accordance with “safe harbor” provisions of the Private Securities Litigation Reform Act of 1995, these statements are accompanied by cautionary language identifying important factors, though not necessarily all such factors, which could cause future outcomes to differ materially from those set forth in forward-looking statements. In particular, expressed or implied statements concerning future actions, future drop downs, volumes, capital requirements, conditions or events, future impact of prior acquisitions, future operating results or the ability to generate sales, the potential exposure of BP Midstream to market risks, and statements relating to expected Adjusted EBITDA, future growth, income, cash flow and the amount of distributions are forward-looking statements. Forward-looking statements are not guarantees of performance. They involve risks, uncertainties and assumptions. Future actions, conditions or events and future results of operations may differ materially from those expressed in these forward-looking statements. Forward-looking statements speak only as of the date of this presentation, and we disclaim any obligation to update such statements for any reason, except as required by law. All forward-looking statements contained in this presentation are expressly qualified in their entirety by the cautionary statements contained or referred to in this paragraph. Many of the factors that will determine these results are beyond our ability to control or predict. These factors include the risk factors described in BP Midstream’s annual report for the year ended December 31, 2018 as filed with the Securities and Exchange Commission (the “SEC”) on February 28, 2019, as updated by our subsequent filings with the SEC. If any of those risks occur, it could cause our actual results to differ materially from those contained in any forward-looking statement. Because of these risks and uncertainties, you should not place undue reliance on any forward-looking statement. This presentation has been prepared by BP Midstream and includes market data and other statistical information from sources believed by BP Midstream to be reliable, including independent industry publications, government publications or
believes these sources are reliable, it has not independently verified the information and cannot guarantee its accuracy and completeness. NON-GAAP FINANCIAL MEASURES BP Midstream has included the non-GAAP financial measures Adjusted EBITDA and cash available for distribution based on information in its financial statements. Adjusted EBITDA and cash available for distribution are supplemental financial measures that management and external users of BP Midstream’s financial statements, such as industry analysts, investors, lenders and rating agencies may use, to assess: (i) BP Midstream’s operating performance as compared to other publicly traded partnerships in the midstream energy industry, without regard to historical cost basis or, in the case of Adjusted EBITDA, financing methods; (ii) the ability of BP Midstream’s business to generate sufficient cash to support its decision to make distributions to its unitholders; (iii) BP Midstream’s ability to incur and service debt and fund capital expenditures; and (iv) the viability of acquisitions and other capital expenditure projects and the returns on investment of various investment opportunities. BP Midstream believes that the presentation of Adjusted EBITDA and cash available for distribution provides useful information to management and investors in assessing its financial condition and results of operations. The GAAP measures most directly comparable to Adjusted EBITDA and cash available for distribution are net income and net cash provided by operating activities. Adjusted EBITDA and cash available for distribution should not be considered as an alternative to GAAP net income or net cash provided by operating activities, respectively. Adjusted EBITDA and cash available for distribution have important limitations as analytical tools because they exclude some but not all items that affect net income and net cash provided by operating activities. Adjusted EBITDA or cash available for distribution should not be considered in isolation or as a substitute for analysis of results as reported under GAAP. Additionally, because Adjusted EBITDA and cash available for distribution may be defined differently by other companies in the industry, BP Midstream’s definition of Adjusted EBITDA and cash available for distribution may not be comparable to similarly titled measures of other companies, thereby diminishing its utility. For reconciliations of Adjusted EBITDA and cash available for distribution to their most directly comparable GAAP measures, see “Supplementary Information”. The Partnership is unable to provide financial guidance for projected net income or net cash provided by operating activities without unreasonable effort, and, therefore, is unable to provide a reconciliation of its Adjusted EBITDA and cash available for distributions projections to net income or net cash provided by operating activities, the most comparable financial measures calculated in accordance with GAAP. The Partnership has not included a reconciliation of projected cash available for distribution to the nearest GAAP financial measure for 2018 because it cannot do so without unreasonable effort and any attempt to do so would be inherently imprecise.
BP MIDSTREAM PARTNERS 4Q & FULL YEAR 2018 RESULTS
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BP MIDSTREAM PARTNERS
BP MIDSTREAM PARTNERS 4Q & FULL YEAR 2018 RESULTS
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BP WHITING REFINERY
BP MIDSTREAM PARTNERS 4Q & FULL YEAR 2018 RESULTS
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BP ATLANTIS Offshore deepwater Gulf of Mexico
BP MIDSTREAM PARTNERS 4Q & FULL YEAR 2018 RESULTS
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1) 4Q18 includes contribution from assets acquired as part of the 2018 asset dropdown. IPO forecast does not include this contribution. 2) Cumulative amounts. 3) As measured by comparing the quarterly distribution declared in relation to 4Q17 (not pro-rated) and the quarterly distribution declared in relation to 4Q18.
Adjusted EBITDA attributable to the Partnership ($ million)1,2
2018 Adjusted EBITDA exceeded IPO forecast
Cash available for distribution to the Partnership ($ million)1,2
2018 Cash Available For Distribution exceeded IPO forecast
Annualized quarterly distribution ($ per common unit)
Mid-teens distribution growth delivered3
IPO forecast IPO forecast MQD $ 37 $ 69 $ 103 $ 144 1Q18 2Q18 3Q18 4Q18 $ 1.05 $ 1.07 $ 1.09 $ 1.17 $ 1.21 4Q17 1Q18 2Q18 3Q18 4Q18 $ 35 $ 69 $ 107 $ 149 1Q18 2Q18 3Q18 4Q18
BP MIDSTREAM PARTNERS 4Q & FULL YEAR 2018 RESULTS
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BP WHITING REFINERY
BP MIDSTREAM PARTNERS 4Q & FULL YEAR 2018 RESULTS
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1) Cleopatra gas volumes are converted to mboed by dividing mmscfd by 5.8. 2) 4Q17 based on proforma asset portfolio. 3) Based on reported revenue from transportation and allowance oil divided by delivered barrels over the same time period.
3Q18 4Q18 4Q17 BP2 Caesar Proteus Diamondback Cleopatra River rouge Mars Endymion Ursa
500 1,000 1,500 2,000 4Q17 3Q18 4Q18 0.00 0.50 1.00 1.50 Total Wholly Owned Assets Mars Mardi Gras Joint Ventures Ursa
BP MIDSTREAM PARTNERS 4Q & FULL YEAR 2018 RESULTS
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1) Rounding convention has been modified to ensure key line items sum correctly. 2) Predecessor financials October 1–29, 2017; BPMP financials October 30–December 31, 2017. 3) Predecessor financials January 1–October 29, 2017; BPMP financials October 30–December 31, 2017. 4) 4Q18 Revenue includes $4.1 million of deficiency revenue recognized under the throughput and deficiency agreements. 5) 4Q17 and 2017 shown subsequent to the IPO.
Operating income Net income subsequent to the IPO Net income Net income attributable to the Partnership
Revenue4 Costs and expenses Income from equity method investments Other income Interest expense, net Income tax expense Less: Predecessor net income prior to the IPO on October 30, 2017 Less: Net income attributable to non-controlling interests Adjusted EBITDA attributable to the Partnership5 Cash available for distribution attributable to the Partnership5
3Q18 4Q172 4Q18 32.1 11.2 20.9 22.6
43.5 8.3 35.2 37.7 34.1
10.7 16.9 17.9 0.1 32.8 29.9 8.1 21.8 23.5 23.3 0.1 2.0 2.9 28.8 11.7 17.1 28.1 3.9 41.3 41.3 4.5 36.8 43.0 40.7
2018 108.2 31.7 76.5 17.9 0.1 69.0 29.9 8.1 21.8 23.5 23.3
39.1 116.4 41.1 75.3 94.4 4.0 165.7 165.7 32.6 133.1 149.4 143.9
BP MIDSTREAM PARTNERS 4Q & FULL YEAR 2018 RESULTS
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Organic and inorganic
Sufficient for
annual distribution growth
Sufficient to support
Existing portfolio ~1.7mboed $5-6m
Gross Debt to Adjusted EBITDA ratio not to exceed 3.5 times; target credit metrics consistent with investment grade
Consistent with
Broadly flat with 20183 3 month LIBOR + 0.85%5
~$1-2m
Consistent with
$160-170m
~$15m
1) Pipeline gross throughput and average revenue/bbl for Mars, Mardi Gras and Ursa joint ventures are presented on a full year, 100% basis. 2) Cleopatra gas volumes are converted to mboed by dividing mmscf/d by 5.8. 3) Portfolio basis. Average revenue/bbl for 2018: Wholly owned: $0.73; Mars $1.25; Mardi Gras JV: $0.65. 4) Subject to change with future dropdown activity and capital structure adjustments. 5) Calculated on balances outstanding under the Partnership’s revolving credit facility. Excludes customary fees, such as a commitment fee of 0.10% and a utilization fee of 0.20%. 6) ‘Total’ includes maintenance capital expenditure and revex for wholly owned assets and maintenance capital incurred by joint ventures. ‘Capex’ is a subset of the ‘Total’ and includes maintenance capital expenditure for wholly owned assets only.
BP MIDSTREAM PARTNERS 4Q & FULL YEAR 2018 RESULTS
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BP MIDSTREAM PARTNERS
BP WHITING REFINERY
BP MIDSTREAM PARTNERS 4Q & FULL YEAR 2018 RESULTS
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BP WHITING REFINERY 1) Minimum volume commitments.
BP MIDSTREAM PARTNERS 4Q & FULL YEAR 2018 RESULTS
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BP MIDSTREAM PARTNERS
1) Not intended to be an exhausted list of future growth projects 2) Hydrocarbons initially in place.
Vito Shell 100 2021 Kaikias Shell 40 2018 Power Nap Shell 35 TBD Amber berjack D Del eliver eries es t to
peline ne Jack St. Malo Chevron 94 2014 Big Foot Chevron 75 2018 Stampede Hess 80 2018
Appomattox Shell 175 2019 Norphlet Various ~65 TBD
Heidelberg Anadarko 80 2015 Mad Dog II BP 110 2022 Atlantis III BP 200 2020 Atlantis options BP TBD TBD Mad Dog options BP TBD TBD Thunder Horse options BP TBD TBD
BP MIDSTREAM PARTNERS 4Q & FULL YEAR 2018 RESULTS
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BP MIDSTREAM PARTNERS
BP THUNDER HORSE Offshore deepwater Gulf of Mexico
BP MIDSTREAM PARTNERS 4Q & FULL YEAR 2018 RESULTS
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BP MIDSTREAM PARTNERS
SS332 Louisiana Offshore Oil Port (LOOP) Green Canyon Walker Ridge Desoto Canyon Mississippi Canyon
Heidelberg Mad Dog Atlantis Neptune Shenzi
SP89E Fourchon
Olympus Mars A Ursa Thunder Hawk Thunder Horse Appomattox Dantzler field Big Bend field Holstein
Expansion 2
Mars oil pipeline Proteus oil pipeline Endymion oil pipeline Ursa oil pipeline Cleopatra gas pipeline Caesar oil pipeline Connecting third party pipeline Future connecting third party pipelines BP-operated platform Non-operated or third party platform Future growth potential Catchment areas Pipeline hub platform BPMP Pipelines Future project – not yet sanctioned Future project - sanctioned Kaikias Map not to scale; for illustrative purposes only
Water Injection
Big Foot Stampede Jack/St Malo
WD143
BP MIDSTREAM PARTNERS 4Q & FULL YEAR 2018 RESULTS
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BP WHITING REFINERY
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BP MIDSTREAM PARTNERS
dropdown inventory pyramid
(i.e. Downstream pipelines & Midstream assets in US fuels & trading business)
may acquire Strong Sponsor Strategic, highly integrated assets to BP Pre-investment by BP Capital recycling alignment
increases
(i.e. new production from sanctioned projects in GoM2)
Minimal or no capital
1) Right of first offer. 2) Gulf of Mexico offshore.
embedded organic distribution growth of mid- teens through 2019
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BP MIDSTREAM PARTNERS 4Q & FULL YEAR 2018 RESULTS
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BP MIDSTREAM PARTNERS 4Q & FULL YEAR 2018 RESULTS
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3.9 Net income Adjusted EBITDA Adjusted EBITDA attributable to the Partnership5
1) Rounding convention has been modified to ensure key line items sum correctly. 2) Predecessor financials October 1–29, 2017; BPMP financials October 30–December 31, 2017. 3) Predecessor financials January 1–October 29, 2017; BPMP financials October 30–December 31, 2017. 4) These amounts represent 100% of the cash distributions from Mars, Ursa, KM Phoenix and Mardi Gras joint ventures prior to distribution to non-controlling interests. 5) 4Q17 and 2017 shown subsequent to the IPO.
Depreciation Income from equity method investments
Add:
Income tax expense Interest expense, net Cash distributions received from equity method investments4
Less:
Adjusted EBITDA attributable to non-controlling interests
3Q18 4Q172 4Q18 43.5 0.7
22.6
32.8 0.7 2.0 29.9 17.9 9.4 23.5 0.1 47.6 41.3 0.7
28.1
48.9
Less:
Distributions of prorated fourth quarter joint venture dividends to prior
Adjusted EBITDA attributable to Predecessor prior to IPO on October 30, 2017
9.5 5.2 11.7
20173 2018 69.0 2.7 25.3 29.9 17.9 9.4 23.5 0.1 109.1 165.7 2.7
94.4
195.8 9.5 66.7 46.4
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BP MIDSTREAM PARTNERS
Adjusted EBITDA attributable to the Partnership Cash available for distribution attributable to the Partnership
1) Rounding convention has been modified to ensure key line items sum correctly. 2) 4Q17 and 2017 shown subsequent to the IPO. 3) Acquisition financing expenses.
Net adjustments from volume deficiency agreements
Add:
Net interest paid/(received) Maintenance capital expenditures
Less:
3Q18 4Q172 4Q18 37.7 (2.7)
34.1 23.5 (0.2) (0.1) 0.1 23.3 43.0 1.8 0.3 40.7
(0.1)
Cash reserves3
20172 2018 23.5 (0.2) (0.1) 0.1 23.3 149.4
143.9
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Net cash provided by operating activities Adjusted EBITDA Adjusted EBITDA attributable to the Partnership4
1) Rounding convention has been modified to ensure key line items sum correctly. 2) Predecessor financials October 1–29, 2017; BPMP financials October 30–December 31, 2017. 3) Predecessor financials January 1–October 29, 2017; BPMP financials October 30–December 31, 2017.. 4) 4Q17 and 2017 shown subsequent to the IPO.
Income tax expense Non-cash adjustments
Add:
Interest expense, net Distributions in excess of earnings from equity method investments Change in operating assets and liabilities
Less:
Adjusted EBITDA attributable to non-controlling interests
3Q18 4Q172 4Q18 45.7
0.1 11.7 37.7 4.3 49.4 35.0 2.0 0.1 (3.3)
23.5 7.2 47.6 40.3
5.9 43.0 4.3 48.9
Less:
prior owners Adjusted EBITDA attributable to Predecessor prior to the IPO on October 30, 2017
5.2 9.4
20173 2018 69.2 25.3 0.1 (8.0) 0.7 9.5 23.5 7.2 109.1 173.8
46.4 149.4 19.7 195.8 0.2 9.4 66.7
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BP MIDSTREAM PARTNERS
1) Rounding convention has been modified to ensure key line items sum correctly. 2) 4Q17 and 2017 shown subsequent to the IPO. 3) Acquisition financing expenses.
Adjusted EBITDA attributable to the Partnership Cash available for distribution attributable to the Partnership
Net adjustments from volume deficiency agreements
Add:
Net interest paid/(received) Maintenance capital expenditures
Less:
3Q18 4Q172 4Q18 37.7 (2.7)
34.1 23.5 (0.2) (0.1) 0.1 23.3 43.0 1.8
Cash reserves3
0.3 40.7 (0.1) 3.9 20172 2018 23.5 (0.2) (0.1) 0.1 23.3 149.4
143.9
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1) Rounding convention has been modified to ensure key line items sum correctly. 2) Calculated by multiplying Adjusted EBITDA for the quarter by 4.
Gross Debt to annualized Adjusted EBITDA attributable to the partnership ratio2
Annualized Adjusted EBITDA attributable to the Partnership2
3Q18 4Q17 4Q18
N/A3 N/A3 172.0 2. 2.7
Gross debt
468.0
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Entity ty/ Asset et Produc duct Ty Type pe BPMP MP Owner ership p Inter eres est BP U P USP SPL Ret etaine ned d Owner ership p Inter eres est Pipel eline e Lengt Length (mile les) Main inlin line Capacity (kbpd) pd) Contrac act Stru ructu ture re % o
timate ted 2019 C 2019 CAFD FD Crude 100.0% – 00 12 475 FERC tariff
Refined Products 100.0% –%0 244 80 FERC tariff Diluent 100.0% –%0 42 135 FERC tariff/ Long term contract Refined 25% –% NA NA Terminalling
Crude 28.5% –%0 163 400 FERC and state tariffs/ Lease dedication; Portion with guaranteed return
Crude 22.69% –% 47 150 FERC and state tariffs/ Lease dedication 65.0% 35.0% Crude 36.4% 19.6% 115 450 Lease dedication Natural Gas 34.5% 18.5% 115 500 Lease dedication Crude 42.3% 22.8% 70 425 Lease dedication Crude 42.3% 22.8% 90 425 Lease dedication
(1) (3) (6) (5) (4) (3)
(2)
Notes continue on next slide
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(1) T he appr
mation pr e se nte d is in thousand bar r e ls pe r day (“kbpd”) with the e xc eption of the appr
e lated to Cle opatr a g as g athe r ing syste m, whic h is pr e se nte d in million standar d c ubic fe et pe r day (“MMsc f/ d”). Pipe line c apac itie s are base d on c ur r e nt ope r ations and var y de pe nding on the spe c ific pr
anspor te d and de live r y point, among othe r fac tor s. (2) T
ibution use d in c alc ulating pe r c e ntag e s shown doe s not g ive effe c t to inc r e me ntal g e ne r al and administr ative expe nse r e late d to be ing a public ly tr aded par tne r ship and othe r expe nse s to be inc ur r e d at the par tne r ship leve l, inc luding c e r tain insur anc e e xpe nse s r e late d to Mar s and e ac h of the Mar di Gr a s Joint Ve ntur e s and the initial $13.3 million annual administr ative fe e paid to BP Pipe line s for r e imbur se me nt to BP Pipe line s and its affiliate s for the pr
tain g e ne r al and administrative se r vic e s to us unde r the omnibus ag r e e me nt. Ple ase r e ad “Ce r tain R e lationships and R e lated Par ty T r ansac tions— Ag r e e me nts Gove r ning the F
mation T r ansac tions— O mnibus Ag r e e me nt.” Ple ase r e ad “Cash Distr ibution Polic y and R e str ic tions on Distr ibutions” for impor tant infor mation as to the assumptions we have made for our financ ial for e c ast and for a r e c onc iliation of c ash available for distr ibution to ne t inc ome for Mar s and e ac h of the Mar di Gr as Joint Ve ntur e s. Our for e c ast is a for war d- looking state me nt and should be r e ad tog ethe r with our historic al financ ia l state me nts and ac c ompanying note s inc lude d e lse whe r e in this pr
ma c onde nse d c ombine d financ ial state me nts and ac c ompanying note s inc lude d e lse whe r e in this pr
inanc ial Condition and R e sults of Ope r ations.” (3) BP has histor ic ally be e n the sole shippe ron BP2 and R ive rR
(4) R epr e se nts Mar s ma inline c apac ity of the appr
sa, Medusa and Olympus pipe line s at the West De lta 143 platfor m c omple x to F
c hon, L
e Mar s has a c onne c tion with Ambe r jac k pipe line for ultimate de live r y to Clove lly, L
he c apac ity of the Mar s pipe line syste m r ang e s fr
ude oil tr anspor te d. (5) Our owne r ship inte r e st and BP Pipe line s’ and its affiliate s’ r e taine d owne r ship inte r e st in e ac h of Cae sar , Cle opatr a, Pr
ndymion r e pr e se nts 20.0% and 80.0% , r e spe c tive ly, of the 56.0% , 53.0%, 65.0% and 65.0% owne r ship inte r e sts in suc h Mar di Gr as Joint Ve ntur e s, r e spe c tive ly, he ld by Mar di Gr as. (6) Our 20.0% inte r e st in Mar di Gr as will be a manag ing me mbe r inte r e st that pr
ig ht to vote BP Pipe line s’ and its affiliate s’ r e taine d owne r ship inte r e st in the Mar di Gr as Joint Ve ntur e s.
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(e.g. 35% of Mardi Gras)