SHELL MIDSTREAM PARTNERS Shell Midstream Partners, L.P. ("we," "us," "our" or "the Partnership") is aDelaware limited partnership formed by Shell plc onMarch 19, 2014 to own and operate pipeline and other midstream assets, including certain assets purchased fromShell Pipeline Company LP ("SPLC") and its affiliates. We conduct our operations either through our wholly-owned subsidiaryShell Midstream Operating LLC or through direct ownership. Our general partner isShell Midstream Partners GP LLC (the "general partner"). References to "Shell" or "Parent" refer collectively to Shell plc and its controlled affiliates, other than us, our subsidiaries and our general partner. The following discussion and analysis should be read in conjunction with the unaudited consolidated financial statements and related notes in this quarterly report and Management's Discussion and Analysis of Financial Condition and Results of Operations in Part II, Item 7 of our Annual Report on Form 10-K for the year endedDecember 31, 2021 (our "2021 Annual Report") and the consolidated financial statements and related notes therein. Our 2021 Annual Report contains a discussion of other matters not included herein, such as disclosures regarding critical accounting policies and estimates and contractual obligations. You should also read the following discussion and analysis together with Risk Factors set forth in our 2021 Annual Report.
Partnership Overview
We own, operate, develop and acquire pipelines and other midstream assets and logistics assets. As ofMarch 31, 2022 , our assets include interests in entities that own (a) crude oil and refined products pipelines and terminals that serve as key infrastructure to transport onshore and offshore crude oil production toGulf Coast and Midwest refining markets and deliver refined products from those markets to major demand centers and (b) storage tanks and financing receivables that are secured by pipelines, storage tanks, docks, truck and rail racks and other infrastructure used to stage and transport intermediate and finished products. Our assets also include interests in entities that own natural gas and refinery gas pipelines that transport offshore natural gas to market hubs and deliver refinery gas from refineries and plants to chemical sites along theGulf Coast .
For a description of our assets, please see Part I, Items 1 and 2. - Business and Properties in our 2021 Annual Report.
2022 developments include:
•Take Private Proposal. OnFebruary 11, 2022 , the Board of Directors of our general partner (the "Board") received a non-binding, preliminary proposal letter from SPLC to acquire all of the Partnership's issued and outstanding common units not already owned by SPLC or its affiliates at a value of$12.89 per each issued and outstanding publicly-held common unit (the "Proposal"). The Board has appointed the conflicts committee to review, evaluate and negotiate the Proposal. Refer to Note 1 - Description of Business - Take Private Proposal in the Notes to the Unaudited Consolidated Financial Statements in this report for additional information.
•Credit Facilities. On
We generate revenue from the transportation, terminaling and storage of crude oil, refined products, and intermediate and finished products through our pipelines, storage tanks, docks, truck and rail racks, generate income from our equity and other investments, and generate interest income from financing receivables on certain logistics assets at theShell Norco Manufacturing Complex (the "Norco Assets"). Our revenue is generated from customers in the same industry, our Parent's affiliates, integrated oil companies, marketers and independent exploration, production and refining companies primarily within theGulf Coast region ofthe United States . We generally do not own any of the crude oil, refinery gas or refined petroleum products we handle, nor do we engage in the trading of these commodities. We therefore have limited direct exposure to risks associated with fluctuating commodity prices, although these risks indirectly influence our activities and results of operations over the long-term.
Notable and certain anticipated 2022 impacts to net income and cash available for distribution ("CAFD") include:
•Planned Turnarounds. Certain offshore connected producers will have planned turnarounds during 2022. We anticipate an impact of approximately$15 million to net income and CAFD from planned turnaround activity in 2022. •Colonial Rate Case. Colonial is currently involved in a rate case with theFederal Energy Regulatory Commission ("FERC"). OnApril 27, 2022 , the Administrative Law Judge issued a second partial initial decision related to Colonial's ongoingFERC rate case addressing the issues not covered in the first partial initial decision issued onDecember 1, 2021 . Colonial has begun to review the decision. Depending upon the final outcome of the case, the 24 -------------------------------------------------------------------------------- potential adoption of such decision in whole or in part by theFERC could adversely affect our equity method investment in Colonial, net income and CAFD. Due in part to the anticipated impacts of the rate case on Colonial's business, the board of directors of Colonial elected not to declare a dividend for the three months endedMarch 31, 2022 . Throughout the first quarter of 2022, we have seen a significant increase in oil prices, most notably due to the ongoing Russian invasion ofUkraine and the associated impacts on the global markets. The responses of oil and gas producers to this situation, including as a result of government sanctions, is evolving and remains uncertain. As we navigate the current turbulent global environment, we anticipate continuing to moderate inorganic growth in our asset base and focusing on the sustainable operation of our core assets, cash preservation and the organic growth of our business throughout 2022.
Executive Overview
Net income was$160 million and net income attributable to the Partnership was$158 million during the three months endedMarch 31, 2022 . We generated cash from operations of$157 million . As ofMarch 31, 2022 , we had cash and cash equivalents of$251 million , total debt of$2,542 million and unused capacity under our credit facilities of$1,016 million .
Our 2022 operations and strategic initiatives demonstrate our continuing focus on our business strategies:
•Maintain operational excellence through prioritization of safety, reliability and efficiency; •Enhanced focus on cash optimization and reduced discretionary project spend; •Focus on advantageous commercial agreements with creditworthy counterparties to enhance financial results over the long-term; and •Optimize existing assets and pursue organic growth opportunities. Over the past two years, our business, as well as the market and economy as a whole, have dealt with unprecedented volatility and uncertainty. Even with these challenges, our assets have largely continued to deliver solid results that have allowed us to execute our business strategies. However, we continue to anticipate certain headwinds that may jeopardize our ability to generate sufficient cash to meet our quarterly obligations, including the pendingFERC rate case at Colonial and ongoing uncertainty in the macro-environment. Further, the conflicts committee appointed by the Board is currently evaluating the Proposal, and the transactions consummated by the Proposal, if consummated, would alter our capital structure. Refer to Note 1 - Description of Business - Take Private Proposal in the Notes to the Unaudited Consolidated Financial Statements in this report for additional information. To the extent the transactions contemplated by the Proposal are not consummated, identifying and executing acquisitions, whether from Shell or from third parties, will remain a key part of our strategy. However, if we do not make acquisitions on economically acceptable terms or if we incur a substantial amount of debt in connection with the acquisitions, our future growth will be limited, and the acquisitions we do make may reduce, rather than increase, our available cash. Our ability to obtain financing or access capital markets may also directly impact our ability to continue to pursue strategic acquisitions. Market demand for equity issued by master limited partnerships ("MLPs") may make it more challenging for us to fund our acquisitions with the issuance of equity in the capital markets. However, we believe our balance sheet offers us flexibility, providing us other financing options such as hybrid securities, purchases of common units by Shell and debt. While we expect to retain this flexibility, we anticipate continuing to moderate inorganic growth in our asset base and focusing on the sustainable operation of our core assets, cash preservation and organic growth of our business.
How We Evaluate Our Operations
Our management uses a variety of financial and operating metrics to analyze our
performance. These metrics are significant factors in assessing our operating
results and profitability and include: (i) revenue (including pipeline loss
allowance ("PLA") from contracted capacity and throughput); (ii) operations and
maintenance expenses (including capital expenses); (iii) net income attributable
to the Partnership; (iv) Adjusted EBITDA (defined below); and (v) CAFD.
Contracted Capacity and Throughput
The amount of revenue our assets generate primarily depends on our transportation and storage services agreements with shippers and the volumes of crude oil, refinery gas and refined products that we handle through our pipelines, terminals and storage tanks.
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The commitments under our transportation, terminaling and storage services
agreements with shippers and the volumes we handle in our pipelines and storage
tanks are primarily affected by the supply of, and demand for, crude oil,
refinery gas, natural gas and refined products in the markets served directly or
indirectly by our assets. This supply and demand is impacted by the market
prices for these products in the markets we serve. The ongoing Russian invasion
of Ukraine and the associated impacts on the global markets has caused, and may
continue to cause, disruptions in the U.S. economy and financial and energy
markets. Responses of oil and gas producers to the changes in demand for, and
price of, oil and natural gas are constantly evolving and unpredictable.
We utilize the commercial arrangements we believe are the most prudent under the market conditions to deliver on our business strategy. The results of our operations will be impacted by our ability to:
•maintain utilization of and rates charged for our pipelines and storage facilities; •utilize the remaining uncommitted capacity on, or add additional capacity to, our pipeline systems; •increase throughput volumes on our pipeline systems by making connections to existing or new third-party pipelines or other facilities, primarily driven by the anticipated supply of, and demand for, crude oil and refined products; and •identify and execute organic expansion projects.
Operations and Maintenance Expenses
Our operations and maintenance expenses consist primarily of:
•labor expenses (including contractor services); •insurance costs (including coverage for our consolidated assets and operated joint ventures); •utility costs (including electricity and fuel); •repairs and maintenance expenses; and •major maintenance costs (related to the terminaling service agreements of the Norco Assets, which are expensed as incurred because the Partnership does not own the related assets). Certain costs naturally fluctuate based on throughput volumes and the grades of crude oil and types of refined products we handle, whereas other costs generally remain stable across broad ranges of throughput and storage volumes, but can vary depending upon the level of both planned and unplanned maintenance activity in the particular period. Our maintenance activity can be impacted by events such as turnarounds, asset integrity work and storms. Our management seeks to maximize our profitability by effectively managing operations and maintenance expenses. While cost effectiveness has always been a focus of the business, it is of increased importance given the current operating environment.
Adjusted EBITDA and Cash Available for Distribution
Adjusted EBITDA and CAFD 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. You should not consider Adjusted EBITDA or
CAFD in isolation or as a substitute for analysis of our results as reported
under GAAP. Additionally, because Adjusted EBITDA and CAFD may be defined
differently by other companies in our industry, our definition of Adjusted
EBITDA and CAFD may not be comparable to similarly-titled measures of other
companies, thereby diminishing their utility.
The GAAP measures most directly comparable to Adjusted EBITDA and CAFD are net
income and net cash provided by operating activities. Adjusted EBITDA and CAFD
should not be considered as an alternative to GAAP net income or net cash
provided by operating activities. Please refer to "Results of Operations -
Reconciliation of Non-GAAP Measures" for the reconciliation of GAAP measures net
income and cash provided by operating activities to non-GAAP measures, Adjusted
EBITDA and CAFD.
We define Adjusted EBITDA as net income before income taxes, interest expense,
interest income, gain or loss from dispositions of fixed assets, allowance oil
reduction to net realizable value, loss from revision of asset retirement
obligation, and depreciation, amortization and accretion, plus cash distributed
to us from equity method investments for the applicable period, less equity
method distributions included in other income and income from equity method
investments. We define Adjusted EBITDA attributable to the Partnership as
Adjusted EBITDA less Adjusted EBITDA attributable to noncontrolling interests
and Adjusted EBITDA attributable to Parent.
We define CAFD as Adjusted EBITDA attributable to the Partnership less
maintenance capital expenditures attributable to the Partnership, net interest
paid by the Partnership, cash reserves, income taxes paid and distributions on
our Series A perpetual convertible preferred units (the "Series A Preferred
Units"), plus net adjustments from volume deficiency payments attributable
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to the Partnership, reimbursements from Parent included in partners' capital,
principal and interest payments received on financing receivables and certain
one-time payments received. CAFD will not reflect changes in working capital
balances.
We believe that the presentation of these non-GAAP supplemental financial measures provides useful information to management and investors in assessing our financial condition and results of operations.
Adjusted EBITDA and CAFD are non-GAAP supplemental financial measures that management and external users of our consolidated financial statements, such as industry analysts, investors, lenders and rating agencies, may use to assess:
•our 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; •the ability of our business to generate sufficient cash to support our decision to make distributions to our unitholders; •our ability to incur and service debt and fund capital expenditures; and •the viability of acquisitions and other capital expenditure projects and the returns on investment of various investment opportunities.
Factors Affecting Our Business and Outlook
We believe key factors that impact our business are the supply of, and demand for, crude oil, natural gas, refinery gas and refined products in the markets in which our business operates. We also believe that our customers' requirements, competition and government regulation of crude oil, refined products, natural gas and refinery gas play an important role in how we manage our operations and implement our long-term strategies. In addition, acquisition opportunities, whether from Shell or third parties, and financing options, will also impact our business. These factors are discussed in more detail below.
Changes in Crude Oil Sourcing and Refined Product Demand Dynamics
To effectively manage our business, we monitor our market areas for both short-term and long-term shifts in crude oil and refined products supply and demand. Changes in crude oil supply such as new discoveries of reserves, declining production in older fields, operational impacts at producer fields and the introduction of new sources of crude oil supply affect the demand for our services from both producers and consumers. In addition, general economic, regulatory, broad market and worldwide health considerations can also affect sourcing and demand dynamics for our services. This includes, but is not limited to, the impacts resulting from the Russian invasion ofUkraine , as well as the lingering effects of the COVID-19 pandemic. One of the strategic advantages of our crude oil pipeline systems is their ability to transport attractively priced crude oil from multiple supply markets to key refining centers along theGulf Coast . Our crude oil shippers periodically change the relative mix of crude oil grades delivered to the refineries and markets served by our pipelines. They also occasionally choose to store crude longer term when the forward price is higher than the current price (a "contango market"). While these changes in the sourcing patterns of crude oil transported or stored are reflected in changes in the relative volumes of crude oil by type handled by our pipelines, our total crude oil transportation revenue is primarily affected by changes in overall crude oil supply and demand dynamics, such as the impacts resulting from the Russian invasion ofUkraine , as well asU.S. exports. Similarly, our refined products pipelines have the ability to serve multiple major demand centers. Our refined products shippers periodically change the relative mix of refined products shipped on our refined products pipelines, as well as the destination points, based on changes in pricing and demand dynamics. While these changes in shipping patterns are reflected in relative types of refined products handled by our various pipelines, our total product transportation revenue is primarily affected by changes in overall refined products supply and demand dynamics, including the impacts resulting from the Russian invasion ofUkraine . Demand can also be greatly affected by refinery performance in the end market, as refined products pipeline demand will increase to fill the supply gap created by refinery issues. We can also be constrained by asset integrity considerations in the volumes we ship. We may elect to reduce cycling on our systems to reduce asset integrity risk, which in turn would likely result in lower revenues. As these supply and demand dynamics shift, we anticipate that we will continue to actively pursue projects that link new sources of supply to producers and consumers and to create new services or capacity arrangements that meet customer requirements. We expect to continue extending our corridor pipelines to provide developing growth regions in theGulf of Mexico with access via our existing corridors to onshore refining centers and market hubs. For example, the Mars system is expanding to address growing production volumes in theGulf of Mexico regions served by Mars. It is expected that the project will be fully operational in 2022. Incremental growth volumes began arriving into the Mars system in the first quarter of 2022, and we expect additional growth volumes to arrive into the system in the latter part of 2022. We believe this strategy will allow our offshore business to grow profitably throughout demand cycles. 27 --------------------------------------------------------------------------------
Changes in
We generate a portion of our revenue under long-term transportation service agreements with shippers, including ship-or-pay agreements and life-of-lease transportation agreements, some of which provide a guaranteed return, and storage service agreements with marketers, pipelines and refiners. Historically, the commercial terms of these long-term transportation and storage service agreements have mitigated volatility in our financial results by limiting our direct exposure to reductions in volumes due to supply or demand variability. Our business could be negatively affected if we are unable to renew or replace our contract portfolio on comparable terms, by sustained downturns or sluggishness in commodity prices, or the economy in general. Our business is also impacted by shifts in supply and demand dynamics, the mix of services requested by our pipeline customers, competition and changes in regulatory requirements affecting our operations. Other factors that can have an effect on our performance include asset integrity or customer interruptions, natural disasters or other events that could lead customers or connecting carriers to invoke force majeure or other defenses to avoid contractual performance. As contracts expire, there are several ways in which the associated revenue could be replaced in the future, such as through re-contracting or spot shipments, the outcome of which will be dependent on market and customer dynamics. The market environment at any given time will dictate the rates, terms and duration of agreements that shippers are willing to enter into, as well as the contracts that best satisfy the needs of our business and that will maximize earnings. As we have grown and broadened our business over the past several years, we have benefited from shifting our reliance away from the results of any one asset. For example, while Zydeco continues to serve an important market, and we strive to maximize the long-term value of the system to both shippers and the pipeline, we have diversified, and will continue to diversify, our risk across products, customers and geographies.
Changes in Commodity Prices and Customers' Volumes
Crude oil prices have fluctuated significantly over the past few years, often with drastic moves in relatively short periods of time. While we saw an increase in both the demand for and price of crude oil throughout 2021, and a significant increase in price in the first few months of 2022, it is not without continued uncertainty. Current global geopolitical and economic instability, particularly as it relates to the ongoing Russian invasion ofUkraine , continues to contribute to future uncertainty, and potential volatility, in financial and commodity markets. One example of such global economic forces impacting crude oil prices was the stalemate amongOrganization of Petroleum Exporting Countries ("OPEC") members and co-operating non-OPEC resource holders (the "OPEC+ alliance"), which ultimately ended in mid-2021 and was resolved when the OPEC+ alliance agreed to phase out the COVID-19 production cuts fromAugust 2021 toDecember 2022 . We expect that the OPEC+ alliance decision will cause the crude oil market to remain relatively tight in the near and medium-term, as this increased production will likely align with the higher global demand. The ongoing Russian invasion ofUkraine and resulting sanctions imposed onRussia by theEuropean Union ,the United States and other countries have further tightened the crude oil market and elevated commodity prices. Although such sanctions do not directly impact our business or our customers, the effects of these measures may indirectly affect our business by affecting the price of crude oil, natural gas, refinery gas and refined products. Additionally, in order to address high oil prices,President Biden recently announced a plan to release 1 million barrels of oil a day for the next 6 months from theU.S. Strategic Petroleum Reserve. The release from theU.S. Strategic Petroleum Reserve is anticipated to start being available in the market inMay 2022 . While the scope of impact is currently unclear, the release could have a downward effect on commodity prices. Our direct exposure to commodity price fluctuations is limited to the PLA provisions in our tariffs. Indirectly, global demand for refined products and chemicals could impact our terminal operations and refined products and refinery gas pipelines, as well as our crude pipelines that feedU.S. manufacturing demand. Likewise, changes in the global market for crude oil could affect our crude oil pipelines and terminals and require expansion capital expenditures to reach growing export hubs. Demand for crude oil, refined products and refinery gas may decline in the areas we serve as a result of decreased production by our customers, depressed commodity prices, decreased third-party investment in the industry, increased competition and other adverse economic factors. Other global events, such as the ongoing Russian invasion ofUkraine and its associated impacts on the global markets, as well as the lingering impacts of the COVID-19 pandemic, could affect the exploration, production and refining industries generally, which, indirectly, may affect our business. However, fixed contracts with volume minimums and demand for tanks for storage are expected to moderate any impact on our terminaling and storage service revenue. Certain of our assets benefit from long-term fee-based arrangements and are strategically positioned to connect crude oil volumes originating from key onshore and offshore production basins to theTexas andLouisiana refining markets, where demand for throughput has remained strong. Historically, with the exception of the impacts of the COVID-19 pandemic, we have not experienced a material decline in throughput volumes on our crude oil pipeline systems as a result of lower crude oil prices. If crude oil prices drop to lower levels, as they did during the height of the COVID-19 pandemic, we will see a reduction in our transportation volumes if production coming into our systems is deferred and our associated allowance oil sales decrease. Our customers may also experience liquidity and credit problems or other unexpected events, which could cause them to defer development or repair projects, avoid our contracts in bankruptcy, invoke force majeure clauses or other defenses to avoid 28 --------------------------------------------------------------------------------
contractual performance, renegotiate our contracts on terms that are less attractive to us or impair their ability to perform under our contracts.
Our throughput volumes on our refined products pipeline systems depend primarily on the volume of refined products produced at connected refineries and the desirability of our end markets. These factors in turn are driven by refining margins, maintenance schedules and market differentials. Refining margins depend on the cost of crude oil or other feedstocks and the price of refined products. These margins are affected by numerous factors beyond our control, including the domestic and global supply of and demand for crude oil and refined products.
Other Changes in Customers' Volumes
Onshore crude transportation volumes were lower in the three months endedMarch 31, 2022 (the "Current Quarter ") versus the three months endedMarch 31, 2021 (the "Comparable Quarter ") primarily due to lower deliveries from certain systems intoHouma in theCurrent Quarter , partially offset by the impact of the COVID-19 pandemic in theComparable Quarter . Offshore crude transportation volumes were lower in theCurrent Quarter versus theComparable Quarter primarily due to lower deliveries from certain connected producers, as well as higher maintenance activities on various systems in the eastern corridor of theGulf Coast . Onshore terminaling and storage volumes decreased in theCurrent Quarter versus theComparable Quarter due to scheduled maintenance at theLockport facility, as well as connecting carrier availability.
Major Maintenance Projects
A project is being completed on the Odyssey system at MP289C to re-route two pipelines around the platform. We expect that the re-route work will be complete by mid-2023. The project will be funded by cash calls to the owners of Odyssey for their proportionate share. As such, we will fund 71% of the project.
For expected capital expenditures in 2022, refer to Capital Resources and Liquidity - Capital Expenditures and Investments.
Major Expansion Projects
The Mars system is expanding to address growing production volumes in theGulf of Mexico regions served by Mars. SPLC has elected to fund the installation of the equipment necessary to enable greater throughput volumes on the system, but the revenue associated with increased throughput volumes will benefit Mars. Two major milestones were reached in 2021 with the placement of the pump module on the platform and the execution of definitive agreements with producers. It is expected that the project will be fully operational in 2022. Incremental growth volumes began arriving into the Mars system in the first quarter of 2022 with the startup of PowerNap, a tie-back to the Shell-operated Olympus production hub. We expect additional growth volumes to arrive into the system in the latter part of 2022. Over the course of the next few years, we are considering expanding the Auger corridor in order to position the system to capture potential growth volumes in that region of theGulf of Mexico . We intend to expand ourLockport facility to accommodate expected additional volumes coming into the Midwest region. This expansion is pending the completion of certain commercial agreements. 29 --------------------------------------------------------------------------------
Customers
We transport and store crude oil, refined products, natural gas and refinery gas for a broad mix of customers, including producers, refiners, marketers and traders, and are connected to other crude oil and refined products pipelines. In addition to serving directly-connectedU.S. Gulf Coast markets, our crude oil and refined products pipelines have access to customers in various regions ofthe United States through interconnections with other major pipelines. Our customers use our transportation and storage services for a variety of reasons. Refiners typically require a secure and reliable supply of crude oil over a prolonged period of time to meet the needs of their specified refining diet and frequently enter into long-term firm transportation agreements to ensure a ready supply of a specific mix of crude oil grades, rate surety and sometimes sufficient transportation capacity over the life of the contract. Similarly, chemical sites require a secure and reliable supply of refinery gas to crackers and enter into long-term firm transportation agreements to ensure steady supply. Producers of crude oil and natural gas require the ability to deliver their product to market and frequently enter into firm transportation contracts to ensure that they will have sufficient capacity available to deliver their product to delivery points with greater market liquidity. Marketers and traders generate income from buying and selling crude oil and refined products to capitalize on price differentials over time or between markets. Our customer mix can vary over time and largely depends on the crude oil and refined products supply and demand dynamics in our markets.
Competition
Our pipeline systems compete primarily with other interstate and intrastate pipelines and with marine and rail transportation. Some of our competitors may expand or construct transportation systems that would create additional competition for the services we provide to our customers. For example, newly-constructed transportation systems in the onshoreGulf of Mexico region may increase competition in the markets where our pipelines operate. In addition, future pipeline transportation capacity could be constructed in excess of actual demand in the market areas we serve, which could reduce the demand for our services, and could lead to the reduction of the rates that we receive for our services. While we do see some variation from quarter-to-quarter resulting from changes in our customers' demand for transportation, we have historically been able to partially mitigate this risk with the longer-term, fixed-rate nature of several of our contracts. Our storage terminal competes with surrounding providers of storage tank services. Some of our competitors have expanded terminals and built new pipeline connections, and third parties may construct pipelines that bypass our location. These, or similar events, could have a material adverse impact on our operations. Our refined products terminals generally compete with other terminals that serve the same markets. These terminals may be owned by major integrated oil and gas companies or by independent terminaling companies. While fees for terminal storage and throughput services are not regulated, they are subject to competition from other terminals serving the same markets. However, our contracts provide for stable, long-term revenue, which is not impacted by market competitive forces. Regulation
Our assets are subject to regulation by various federal, state and local
agencies; for example, our interstate common carrier pipeline systems are
subject to economic regulation by the
OnApril 8, 2022 , thePipeline and Hazardous Materials Safety Administration ("PHMSA") published a new final rule titled "Required valve installation and minimum rupture detection standards." This rule has amendments to both the liquid and gas pipeline safety regulations around valve placement and rupture/leak detection. The majority of the requirements regarding valve placement and rupture detection in this new rule apply to new construction or pipeline replacements. There are some provisions around emergency response and emergency notifications that apply to all regulated lines. The rule is being reviewed to determine the impact to our operations, and an action plan will be created to adjust processes and procedures as needed for compliance with the rule. We have a 16.125% ownership interest in Colonial, which owns and operates a pipeline that runs throughout the southern and easternUnited States (the "Colonial pipeline"). OnMay 7, 2021 , the computerized equipment managing the Colonial pipeline was the target of a cyberattack, and while Colonial proactively took certain systems offline to contain the threat, it paid a ransom in the form of cryptocurrency to regain control of the equipment. For additional information about cybersecurity risks and the cybersecurity programs and protocols we have in place to protect against those risks, see Part I, Items 1 and 2. Business and Properties - Information Technology and Cyber-security and Item 1A. Risk Factors - IT/Cyber-security/Data Privacy/Terrorism Risks in our 2021 Annual Report. InMay 2021 , theTransportation Security Administration ("TSA") issued a security directive, their initial regulatory response to the Colonial pipeline ransomware attack. The first security directive requires pipeline owners and operators to report confirmed 30 -------------------------------------------------------------------------------- and potential cybersecurity incidents to theCybersecurity and Infrastructure Security Agency ("CISA") within 12 hours of discovery, designate a cybersecurity coordinator to be available 24 hours a day, seven days a week, review current practices and identify any gaps and related remediation measures to address cyber-related risks and report the results to theTSA and CISA within 30 days. InJuly 2021 , theTSA issued a second security directive imposing additional obligations on owners and operators ofTSA -designated critical pipelines. In addition to the requirements under the first directive, the second directive requires pipeline owners and operators to develop and implement specific mitigation measures to protect against ransomware attacks and other known threats to information technology and operational technology systems, and a cybersecurity contingency and recovery plan as well as to conduct cybersecurity assessments. We are in the process of reviewing these new directives. OnJune 14, 2021 , as part of the self-executing provisions of the Protecting our Infrastructure of Pipelines and Enhancing Safety Act of 2020, PHMSA published an advisory bulletin requiring operators to update inspection and maintenance plans to address eliminating hazardous leaks and minimizing releases of natural gas byDecember 27, 2021 . This advisory bulletin is expected to have minimal impact on our operations but will require minor updates to our inspection and maintenance manuals. In early 2021, PHMSA issued a revised map of the ecological High Consequence Areas ("HCAs") in theGulf of Mexico . This revised map expanded the ecological HCA of theGulf of Mexico to include previously excluded dolphin and whale habitats. The HCA now encompasses most of theGulf of Mexico . This places most liquid pipelines in theGulf of Mexico in an HCA and subject to the assessment requirements of 49 CFR 195.452. This may impact certain operational activity such as the frequency at which certain inspections need to be performed and the types of inspections required at those intervals. The holistic impact to our business is uncertain at this time, but we expect that all companies with comparableGulf of Mexico operations will be similarly impacted. InMay 2021 , Zydeco, Mars andLOCAP filed with theFERC to decrease rates subject to theFERC's indexing adjustment methodology that were previously at their ceiling levels by 0.5812% starting onJuly 1, 2021 . OnJanuary 20, 2022 , theFERC filed an order requiring carriers to recalculate their ceiling levels and file any necessary rate reductions to be effectiveMarch 1, 2022 using a revised formula. All theFERC ceiling levels were recalculated as directed and necessary rate reductions filed before theMarch 1 deadline. Rate complaints are currently pending at theFERC inDocket Nos . OR18-7-002, et al. challenging Colonial's tariff rates, its market power and its practices and charges related to transmix and product volume loss. A partial initial decision from the Administrative Law Judge was issued onDecember 1, 2021 finding that Colonial lacks the ability to exercise market power in the 90-countyGulf Coast geographic origin market, but no longer lacks the ability to exercise market power in the 16-county Tuscaloosa-Moundville geographic origin market. The partial initial decision also found that Colonial's method of net recoveries of product loss is unjust and unreasonable and that Colonial should adopt a fixed allowance oil deduction for shortages in deliveries and determine the amount of reparations, if any, owed to shippers. This document is a recommendation to theFERC based on the facts surrounding the case, the law andFERC precedent. TheFERC may decide to adopt the recommendations made or make different determinations. If theFERC adopts the partial initial decision in whole, in addition to the changes in product loss charges described above, which may adversely affect Colonial, Colonial's rates in respect of the 16-county Tuscaloosa-Moundville geographic origin market will no longer be market-based and could be reduced. Subsequently, onApril 27, 2022 , the Administrative Law Judge issued a second partial initial decision related to Colonial's ongoingFERC rate case addressing the issues not covered in the first partial initial decision issued onDecember 1, 2021 . Colonial has begun to review the decision. The parties to the case will be filing briefs to argue for or against the recommendations, which will be considered by theFERC in its ruling. The timing of such ruling is unknown. In 2020, theFERC commenced the five-year review of the oil pipeline rate index formula in Docket No. RM20-14-000. TheFERC issued an initial order onDecember 17, 2020 adopting a new formula of PPI-FG plus 0.78% for the next five-year period commencing onJuly 1, 2021 . OnJanuary 20, 2022 , theFERC issued an order on rehearing revising the formula set in theDecember 17, 2020 order to PPI-FG minus 0.21%. The lower indexing adjustment resulted from theFERC adjusting the data set used to assess pipeline cost changes; taking into account the elimination of the income tax allowance and previously accrued accumulated deferred income tax balances for MLP-owned pipelines; and using updated cost data for 2014. The rehearing order required pipelines to recalculate their rate ceiling levels using the PPI-FG minus 0.21% formula for the periodJuly 1, 2021 toJune 30, 2022 . For any rate that exceeded the recalculated ceiling level, the pipeline was required to file a rate reduction with theFERC to be effectiveMarch 1, 2022 . A judicial appeal on theFERC's order on rehearing has been filed with theU.S. Court of Appeals for the Fifth Circuit by a group of carriers. Similarly, a group of shippers filed a request for rehearing at theFERC , and theFERC issued a tolling order to extend its time to consider the matter. TheFERC filed a motion to hold the matter in abeyance at the Fifth Circuit until it was ruled on the rehearing request. We do not expect these rate recalculations to have a material effect on our financial position, operating results or cash flows. 31 --------------------------------------------------------------------------------
For more information on federal, state and local regulations affecting our business, please read Part I, Items 1 and 2. Business and Properties in our 2021 Annual Report.
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The following tables and discussion are a summary of our results of operations,
including a reconciliation of Adjusted EBITDA and CAFD to net income and net
cash provided by operating activities, the most directly comparable GAAP
financial measures, for each of the periods indicated.
Three Months Ended
2022 2021
Revenue $ 135 $ 139
Costs and expenses
Operations and maintenance 41 38
Cost of product sold 9 4
Impairment of fixed assets - 3
General and administrative 13 12
Depreciation, amortization and accretion 12 13
Property and other taxes 5 5
Total costs and expenses 80 75
Operating income 55 64
Income from equity method investments 108 102
Other income 10 14
Investment and other income 118 116
Interest income 8 8
Interest expense 21 21
Income before income taxes 160 167
Income tax expense - -
Net income 160 167
Less: Net income attributable to noncontrolling interests 2 4
Net income attributable to the Partnership 158 163
Preferred unitholder's interest in net income attributable to the Partnership
12 12
Limited Partners' interest in net income attributable to the Partnership's common unitholders
$ 146 $ 151
Adjusted EBITDA attributable to the Partnership (1) $
182
$
157
(1) For a reconciliation of Adjusted EBITDA and CAFD attributable to the Partnership to their most comparable GAAP measures, please read "-Reconciliation of Non-GAAP Measures."
33
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Three Months Ended March 31,
Pipeline throughput (thousands of barrels per day) (1) 2022 2021
Zydeco - Mainlines 535 641
Zydeco - Other segments 43 18
Zydeco total system 578 659
Amberjack total system 340 332
Mars total system 488 498
Bengal total system 305 350
Poseidon total system 239 338
Auger total system 39 95
Delta total system 224 243
Na Kika total system 72 51
Odyssey total system 97 138
Colonial total system 2,422 1,995
Explorer total system 464 443
Mattox total system (2) 120 104
LOCAP total system 726 820
Other systems 452 518
Terminals (3) (4)
Lockport terminaling throughput and storage volumes 229 251
Revenue per barrel ($ per barrel)
Zydeco total system (5) $ 0.71 $ 0.47
Amberjack total system (5) 2.37 2.43
Mars total system (5) 1.27 1.33
Bengal total system (5) 0.36 0.41
Auger total system (5) 1.83 1.69
Delta total system (5) 0.66 0.66
Na Kika total system (5) 0.77 1.06
Odyssey total system (5) 0.98 0.98
Lockport total system (6) 0.22 0.21
Mattox total system (7) 1.52 1.52
(1) Pipeline throughput is defined as the volume of delivered barrels. For
additional information regarding our pipeline and terminal systems, refer to
Part I, Items 1 and 2. - Business and Properties - Our Assets and Operations in
our 2021 Annual Report.
(2) The actual delivered barrels for Mattox are disclosed in the above table for
the comparative periods. However, Mattox is billed by monthly minimum quantity
per dedication and transportation agreements. Based on the contracted volume
determined in the agreements, the thousands of barrels per day (for revenue
calculation purposes) for Mattox are 170 and 154 barrels per day for the three
months ended March 31, 2022 and March 31, 2021 , respectively.
(3) Terminaling throughput is defined as the volume of delivered barrels and
storage is defined as the volume of stored barrels.
(4) Refinery Gas Pipeline and our refined products terminals are not included
above as they generate revenue under transportation and terminaling service
agreements, respectively, that provide for guaranteed minimum revenue and/or
throughput.
(5) Based on reported revenues from transportation and allowance oil divided by
delivered barrels over the same time period. Actual tariffs charged are based on
shipping points along the pipeline system, volume and length of contract.
(6) Based on reported revenues from transportation and storage divided by
delivered and stored barrels over the same time period. Actual rates are based
on contract volume and length.
(7) Mattox is billed at a fixed rate of $1.52 per barrel for the monthly minimum
quantity in accordance with the terms of dedication and transportation
agreements.
34--------------------------------------------------------------------------------
Reconciliation of Non-GAAP Measures
The following tables present a reconciliation of Adjusted EBITDA and CAFD to net income and net cash provided by operating activities, the most directly comparable GAAP financial measures, for each of the periods indicated.
Please read "-Adjusted EBITDA and Cash Available for Distribution" for more information.
Three Months Ended
2022 2021
Reconciliation of Adjusted EBITDA and Cash Available for
Distribution to Net Income
Net income $ 160 $ 167
Add:
Impairment of fixed assets - 3
Depreciation, amortization and accretion 16 16
Interest income (8) (8)
Interest expense 21 21
Cash distributions received from equity method investments 111 123
Less:
Equity method distributions included in other income 8 14 Income from equity method investments 108 102 Adjusted EBITDA (1) 184 206
Less:
Adjusted EBITDA attributable to noncontrolling interests 2 5 Adjusted EBITDA attributable to the Partnership 182 201
Less:
Series A Preferred Units distribution 12 12 Net interest paid by the Partnership (2) 21 21 Maintenance capex attributable to the Partnership 2 2
Add:
Principal and interest payments received on financing receivables
7 9
Net adjustments from volume deficiency payments
attributable to the Partnership 3 (2)
Cash available for distribution attributable to the Partnership's common unitholders
$
157
(1) Excludes principal and interest payments received on financing receivables. (2) Amount represents both paid and accrued interest attributable to the period.
35
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Three Months Ended
2022 2021
Reconciliation of Adjusted EBITDA and Cash Available for Distribution to Net Cash Provided by Operating Activities Net cash provided by operating activities
$ 157 $ 166
Add:
Interest income (8) (8)
Interest expense 21 21
Return of investment 16 12
Less:
Change in deferred revenue and other unearned income 6 -
Change in other assets and liabilities (4) (15)
Adjusted EBITDA (1) 184 206
Less:
Adjusted EBITDA attributable to noncontrolling interests 2 5 Adjusted EBITDA attributable to the Partnership 182 201
Less:
Series A Preferred Units distribution 12 12 Net interest paid by the Partnership (2) 21 21 Maintenance capex attributable to the Partnership 2 2
Add:
Principal and interest payments received on financing receivables
7 9
Net adjustments from volume deficiency payments attributable to the Partnership
3 (2)
Cash available for distribution attributable to the Partnership's common unitholders
$
157
(1) Excludes principal and interest payments received on financing receivables. (2) Amount represents both paid and accrued interest attributable to the period.
36
--------------------------------------------------------------------------------Revenues
Total revenue decreased by$4 million in theCurrent Quarter as compared to theComparable Quarter comprised of decreases in transportation services revenue of$9 million and in lease revenue of$1 million in theCurrent Quarter versus theComparable Quarter . These decreases are partially offset by increases of$5 million attributable to product revenue and$1 million attributable to terminaling services revenue in theCurrent Quarter versus theComparable Quarter . Transportation services revenue decreased for Pecten primarily due to lower deliveries from certain producers, as well as lower throughput on Odyssey as a result of higher maintenance activities from producers in theCurrent Quarter . Additionally, there were lower deliveries from certain systems intoHouma in theCurrent Quarter . These decreases were partially offset by higher revenue on Zydeco due to increased shipments on higher tariff routes in theCurrent Quarter , primarily as a result of the COVID-19 pandemic in theComparable Quarter .
Lease revenue decreased as a result of the sale of the Anacortes Assets in the second quarter of 2021.
Product revenue increased by
Terminaling services revenue increased primarily due to higher revenue resulting from a contractual inflation adjustment in the latter part of 2021 related to the service components of the terminaling services agreements for theNorco Assets.
Costs and Expenses
Total costs and expenses increased$5 million in theCurrent Quarter as compared to theComparable Quarter primarily due to an increase of$3 million of operations and maintenance expenses,$5 million of cost of product sold and$1 million of general and administrative expenses. These increases were partially offset by decreases of$3 million as a result of no impairment of fixed assets inCurrent Quarter and$1 million of depreciation expense. Operations and maintenance expenses increased in theCurrent Quarter versus theComparable Quarter mainly as a result of higher project spend and maintenance activities in theCurrent Quarter , partially offset by larger physical gains on allowance oil in theCurrent Quarter .
Cost of product sold increased primarily as a result of higher sales of
allowance oil in the
General and administrative expenses increased in theCurrent Quarter versus theComparable Quarter primarily due to an increase in professional services and associated fees. Investment and Other Income Investment and other income increased$2 million in theCurrent Quarter as compared to theComparable Quarter . Income from equity method investments increased$6 million primarily as a result of higher equity earnings from Colonial and Explorer in theCurrent Quarter . Other income decreased by$4 million primarily related to$6 million of lower distributions from Poseidon in theCurrent Quarter , partially offset by the receipt of$2 million of insurance proceeds in theCurrent Quarter related to hurricane impacts in the third quarter of 2021.
Interest Income and Expense
Interest income and interest expense was consistent in the
37--------------------------------------------------------------------------------
Capital Resources and Liquidity
We expect our ongoing sources of liquidity to include cash generated from operations, borrowings under our credit facilities and our ability to access the capital markets. We believe this access to credit along with cash generated from operations will be sufficient to meet our short-term working capital requirements and long-term capital expenditure requirements and to make quarterly cash distributions. Our liquidity as ofMarch 31, 2022 was$1,267 million , consisting of$251 million cash and cash equivalents and$1,016 million of available capacity under our credit facilities.
Credit Facility Agreements
As of
Total Capacity Current Interest Rate Maturity Date
2021 Ten Year Fixed Facility $ 600 2.96 % March 16, 2031
Ten Year Fixed Facility 600 4.18 % June 4, 2029
Seven Year Fixed Facility 600 4.06 % July 31, 2025
Five Year Revolver due July 2023
(1) 760 1.25 % July 31, 2023
Five Year Revolver due December
2022 (1) 1,000 1.26 % December 1, 2022
(1) These revolving credit facilities will expire in 2022 and 2023, respectively, and as such, we are currently assessing our options for renewal.
OnJune 30, 2021 , Zydeco entered into a termination of revolving loan facility agreement withShell Treasury Center (West) Inc. ("STCW") to terminate the 2019 Zydeco Revolver. Zydeco had not borrowed any funds under this facility, and therefore, no further obligations existed at the time of termination. OnMarch 16, 2021 , we entered into a ten-year fixed rate credit facility with STCW with a borrowing capacity of$600 million (the "2021 Ten Year Fixed Facility"). The 2021 Ten Year Fixed Facility bears an interest rate of 2.96% per annum and matures onMarch 16, 2031 . The 2021 Ten Year Fixed Facility was fully drawn onMarch 23, 2021 , and the borrowings were used to repay the borrowings under, and replace, the Five Year Fixed Facility. Refer to Note 5 - Related Party Debt in the Notes to the Unaudited Consolidated Financial Statements in this report for additional information. Borrowings under the Five Year Revolver dueJuly 2023 and the Five Year Revolver dueDecember 2022 bear interest at the three-month London Interbank Offered Rate ("LIBOR") rate plus a margin or, in certain instances (including if LIBOR is discontinued), at an alternate interest rate as described in each respective revolver. LIBOR is being discontinued globally, and as such, a new benchmark will take its place. We are in discussion with our Parent to further clarify the reference rate(s) applicable to our revolving credit facilities once LIBOR is discontinued, and once determined, will assess the financial impact, if any. Our weighted average interest rate for both the three months endedMarch 31, 2022 andMarch 31, 2021 was 3.1%. The weighted average interest rate includes drawn and undrawn interest fees, but does not consider the amortization of debt issuance costs or capitalized interest. A 1/8 percentage point (12.5 basis points) increase in the interest rate on the total variable rate debt of$744 million as ofMarch 31, 2022 would increase our consolidated annual interest expense by approximately$1 million . We will need to rely on the willingness and ability of our related party lender to secure additional debt, our ability to use cash from operations and/or obtain new debt from other sources to repay/refinance such loans when they come due and/or to secure additional debt as needed.
As of
For definitions and additional information on our credit facilities, refer to Note 5 - Related Party Debt in the Notes to the Unaudited Consolidated Financial Statements in this report and Note 8 - Related Party Debt in the Notes to the Consolidated Financial Statements included in Part II, Item 8 in our 2021 Annual Report.
Cash Flows from Our Operations
Operating Activities. We generated$157 million in cash flow from operating activities in theCurrent Quarter compared to$166 million in theComparable Quarter . The decrease in cash flows was primarily driven by lower undistributed equity earnings from our equity method investments in theCurrent Quarter . This decrease was partially offset by the timing of receipt of receivables and payment of accruals. 38 -------------------------------------------------------------------------------- Investing Activities. Our cash flow provided by investing activities was$14 million in theCurrent Quarter compared to$9 million in theComparable Quarter . The increase in cash flow provided by investing activities was primarily due to a higher return of investment and lower contribution to investment in theCurrent Quarter compared to theComparable Quarter , partially offset by higher capital expenditures in theCurrent Quarter compared toComparable Quarter . Financing Activities. Our cash flow used in financing activities was$281 million in theCurrent Quarter compared to$178 million in theComparable Quarter . The increase in cash flow used in financing activities was primarily due to partial repayment of outstanding debt in theCurrent Quarter . This increase was partially offset by lower distributions to unitholders and non-controlling interests in theCurrent Quarter , as well as a prepayment fee paid in theComparable Quarter .
Capital Expenditures and Investments
Our operations can be capital intensive, requiring investments to maintain, expand, upgrade or enhance existing operations and to meet environmental and operational regulations. Our capital requirements consist of maintenance capital expenditures and expansion capital expenditures. Examples of maintenance capital expenditures are those made to replace partially or fully depreciated assets, to maintain the existing operating capacity of our assets and to extend their useful lives, or other capital expenditures that are incurred in maintaining existing system volumes and related cash flows. In contrast, expansion capital expenditures are those made to acquire additional assets to grow our business, to expand and upgrade our systems and facilities and to construct or acquire new systems or facilities. We regularly explore opportunities to improve service to our customers and maintain or increase our assets' capacity and revenue. We may incur substantial amounts of capital expenditures in certain periods in connection with large maintenance projects that are intended to only maintain our assets' capacity or revenue. We incurred capital expenditures and investments of$2 million and$4 million for theCurrent Quarter and theComparable Quarter , respectively. The decrease in capital expenditures and investments in theCurrent Quarter as compared to theComparable Quarter was primarily due to a decrease in capital contributions for our interest inPermian Basin . A summary of our capital expenditures and investments is shown in the table below: Three Months Ended March 31, 2022 2021 Expansion capital expenditures $ - $ - Maintenance capital expenditures 2 1 Total capital expenditures paid 2 1 (Decrease) increase in accrued capital expenditures - 1 Total capital expenditures incurred 2 2 Contributions to investment - 2 Total capital expenditures and investments $ 2 $ 4 39
--------------------------------------------------------------------------------
We expect total capital expenditures and investments to be approximately
Actual Expected
Nine Months Total Expected
Three Months Ended Ending December 2022 Capital
March 31, 2022 31, 2022 ExpendituresExpansion capital expenditures
Pecten $ - $ 3 $ 3 Total expansion capital expenditures incurred - 3 3
Maintenance capital expenditures
Zydeco $ 1 $ 2 $ 3 Pecten - 2 2 Triton - 2 2 Odyssey 1 29 30 Total maintenance capital expenditures incurred 2 35 37 Contributions to investment - 1 1 Total capital expenditures and investments $ 2 $ 39 $ 41
Expansion and Maintenance Expenditures
Pecten had no expansion capital expenditures for the three months ended
Zydeco's maintenance capital expenditures for the three months endedMarch 31, 2022 were$1 million , primarily for theHouma motor control center upgrade. We expect Zydeco's maintenance capital expenditures to be approximately$2 million for the remainder of 2022, of which approximately$1 million is related to theHouma tank maintenance projects and$1 million is related to the upgrade of theHouma motor control center. Pecten's maintenance capital expenditures for the three months endedMarch 31, 2022 were less than$1 million , and we expect Pecten's maintenance capital expenditures to be approximately$2 million for the remainder of 2022. These expected expenditures relate to maintenance on theLockport terminal and the Auger system. Triton had no maintenance capital expenditures for the three months endedMarch 31, 2022 , and we expect Triton's maintenance capital expenditures to be approximately$2 million for the remainder of 2022, of which approximately$1 million is related to theSeattle truck, tank and control center upgrades. The remaining maintenance capital expenditure is related to various other routine maintenance projects. Odyssey's maintenance capital expenditures for the three months endedMarch 31, 2022 were$1 million related to a project at MP289C to re-route two pipelines around the platform. We expect Odyssey's maintenance capital expenditures to be approximately$29 million for the remainder of 2022 related to this pipeline re-route project.
We do not expect any maintenance capital expenditures for Sand Dollar in 2022.
We anticipate that capital expenditures for the remainder of the year will be funded primarily with cash from operations.
Capital Contributions
In accordance with the Member Interest Purchase Agreement datedOctober 16, 2017 , pursuant to which we acquired a 50% interest inPermian Basin , we will make capital contributions for our pro rata interest inPermian Basin to fund capital and other expenditures, as approved by a supermajority (75%) vote of the members. We did not make any capital contribution in the three months endedMarch 31, 2022 , and expect to make approximately$1 million in capital contributions during the remainder of 2022.
Off-Balance Sheet Arrangements
We have not entered into any transactions, agreements or other contractual arrangements that would result in off-balance sheet liabilities.
40
--------------------------------------------------------------------------------Environmental Matters and Compliance Costs
Our operations are subject to extensive and frequently changing federal, state and local laws, regulations and ordinances relating to the protection of the environment. Among other things, these laws and regulations govern the emission or discharge of pollutants into or onto the land, air and water, the handling and disposal of solid and hazardous wastes and the remediation of contamination. As with the industry in general, compliance with existing and anticipated environmental laws and regulations increases our overall cost of business, including our capital costs to construct, maintain, operate and upgrade equipment and facilities. While these laws and regulations affect our maintenance capital expenditures and net income, we believe they do not affect our competitive position, as the operations of our competitors are similarly affected. We believe our facilities are in substantial compliance with applicable environmental laws and regulations. However, these laws and regulations are subject to changes, or to changes in the interpretation of such laws and regulations, by regulatory authorities, and continued and future compliance with such laws and regulations may require us to incur significant expenditures. Additionally, violation of environmental laws, regulations and permits can result in the imposition of significant administrative, civil and criminal penalties, injunctions limiting our operations, investigatory or remedial liabilities or construction bans or delays in the construction of additional facilities or equipment. Additionally, a release of hydrocarbons or hazardous substances into the environment could, to the extent the event is not insured, subject us to substantial expenses, including costs to comply with applicable laws and regulations and to resolve claims by third parties for personal injury or property damage or claims by theU.S. federal government or state governments for natural resources damages. These impacts could directly and indirectly affect our business and have an adverse impact on our financial position, results of operations and liquidity if we do not recover these expenditures through the rates and fees we receive for our services. We believe our competitors must comply with similar environmental laws and regulations. However, the specific impact on each competitor may vary depending on a number of factors, including, but not limited to, the type of competitor and location of its operating facilities. For additional information, refer to Environmental Matters, Items 1 and 2. Business and Properties in our 2021 Annual Report. We accrue for environmental remediation activities when the responsibility to remediate is probable and the amount of associated costs can be reasonably estimated. As environmental remediation matters proceed toward ultimate resolution or as additional remediation obligations arise, charges in excess of those previously accrued may be required. New or expanded environmental requirements, which could increase our environmental costs, may arise in the future. We believe we substantially comply with all legal requirements regarding the environment; however, as not all of the associated costs are fixed or presently determinable (even under existing legislation) and may be affected by future legislation or regulations, it is not possible to predict all of the ultimate costs of compliance, including remediation costs that may be incurred and penalties that may be imposed.
Critical Accounting Policies and Estimates
Our critical accounting policies and estimates are set forth in Part II, Item 7.
Management's Discussion and Analysis of Financial Condition and Results of
Operation - Critical Accounting Policies and Estimates in our 2021 Annual
Report. As of
41
--------------------------------------------------------------------------------
CAUTIONARY STATEMENT REGARDING FORWARD-LOOKING STATEMENTS
This report includes forward-looking statements. You can identify our
forward-looking statements by the words "anticipate," "estimate," "believe,"
"budget," "continue," "could," "intend," "may," "plan," "potential," "predict,"
"seek," "should," "would," "expect," "objective," "projection," "forecast,"
"goal," "guidance," "outlook," "effort," "target" and similar expressions.
We based the forward-looking statements on our current expectations, estimates
and projections about us and the industries in which we operate in general. We
caution you these statements are not guarantees of future performance as they
involve assumptions that, while made in good faith, may prove to be incorrect,
and involve risks and uncertainties we cannot predict. In addition, we based
many of these forward-looking statements on assumptions about future events that
may prove to be inaccurate. Accordingly, our actual outcomes and results may
differ materially from what we have expressed in the forward-looking statements.
Any differences could result from a variety of factors, including the following:
•The outcome of the non-binding, preliminary proposal made by SPLC to acquire
all of our issued and outstanding common units not already owned by SPLC or its
affiliates.
•The continued ability of Shell and our non-affiliate customers to satisfy their
obligations under our commercial and other agreements.
•The volume of crude oil, refined petroleum products and refinery gas we
transport or store and the prices that we can charge our customers.
•The tariff rates with respect to volumes that we transport through our
regulated assets, which rates are subject to review and possible adjustment
imposed by federal and state regulators.
•Changes in revenue we realize under the loss allowance provisions of our fees
and tariffs resulting from changes in underlying commodity prices.
•Our ability to renew or replace our third-party contract portfolio on
comparable terms.
•Fluctuations in the prices for crude oil, refined petroleum products and
refinery gas, including fluctuations due to political or economic measures taken
by various countries.
•The level of production of refinery gas by refineries and demand by chemical
sites.
•The level of onshore and offshore (including deepwater) production and demand
for crude oil by U.S. refiners.
•Changes in global economic conditions and the effects of a global economic
downturn on the business of Shell and the business of its suppliers, customers,
business partners and credit lenders.
•The ongoing COVID-19 pandemic and related governmental regulations and travel
restrictions (including our vaccine mandate for offshore employees), and any
resulting reduction in the global demand for oil and natural gas.
•Availability of acquisitions and financing for acquisitions on our expected
timing and acceptable terms.
•Changes in, and availability to us, of the equity and debt capital markets.
•Liabilities associated with the risks and operational hazards inherent in
transporting and/or storing crude oil, refined petroleum products and refinery
gas.
•Curtailment of operations or expansion projects due to unexpected leaks, spills
or severe weather disruption, including disruptions caused by hurricanes; riots,
strikes, lockouts or other industrial disturbances; or failure of information
technology systems due to various causes, including unauthorized access or
attack.
•Costs or liabilities associated with federal, state and local laws and
regulations, including those that may be implemented by the current U.S.
presidential administration, relating to environmental protection and safety,
including spills, releases and pipeline integrity.
•Costs associated with compliance with evolving environmental laws and
regulations on climate change.
•Costs associated with compliance with safety regulations and system maintenance
programs, including pipeline integrity management program testing and related
repairs.
•Changes in tax status or applicable tax laws.
•Changes in the cost or availability of third-party vessels, pipelines, rail
cars and other means of delivering and transporting crude oil, refined petroleum
products and refinery gas.
•Direct or indirect effects on our business resulting from actual or threatened
terrorist incidents or acts of war, including the ongoing Russian invasion of
Ukraine , its associated impacts on global commodity markets and the resulting
political and economic sanctions on Russia .
•The effect of releases from the U.S. Strategic Petroleum Reserve.
•The factors generally described in Part I, Item 1A. Risk Factors in our 2021
Annual Report.
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