Northern Michigan Pipeline Symposium (June 2014)
Frequently Asked Questions on Pipelines in Northern Michigan and Enbridge Line 5
The following questions were submitted in advance of the Northern Michigan Pipeline Symposium. Answers below were compiled from a number of sources including the presentations and panel question and answer session at the symposium as well as Tip of the Mitt Watershed Council research. We will continue to seek answers to other questions that were submitted, but are not answered below.
What governmental agencies regulate pipelines?Pipelines are regulated by a number of federal, state, and local government agencies:
What regulatory agency approves changes in pipeline capacity?
Projects of a certain size or that involve a certain number of miles of construction require notification to PHMSA. The regulatory scheme for pipeline expansions focuses on operating pressure because operating pressure is what causes stress on a pipeline. However, capacity changes can occur without ever changing the established maximum operating pressure on a pipeline system. It is not uncommon for companies to increase capacity through other means such as adding compressor stations or using drag reducing agents to decrease the friction along the pipeline wall to reduce the horsepower needed to move the product. These types of actions do not fall under the federal regulations because they are not revising the maximum operating pressure.
Enbridge submitted notification to PHMSA to increase capacity of Line 5 in May of 2012. PHMSA met with Enbridge and got a briefing on what the project entailed, formed a special inspection, and upon completion of the project, reviewed their hydrostatic testing records.
How many regulatory staff are there to monitor safety of pipelines across the country and, specifically, how many for Michigan?
The Pipeline and Hazardous Materials Safety Administration (PHMSA) is authorized for 140 inspection and enforcement personnel nationwide and 25 of those are located within the Central Region, which is responsible for pipeline safety in Michigan.
The State of Michigan also has a role with pipeline safety of natural gas pipelines. The State, through the Michigan Public Service Commission (MPSC), conducts inspections and enforcement for intrastate natural gas pipelines as well as inspections of interstate natural gas pipelines. Because interstate pipelines cross state borders, PHMSA is still responsible for enforcement of these lines. The Michigan Public Service Commission currently has 8 full time engineers in the state dedicated to pipeline inspections for natural gas pipelines.
Why does the State not have authority over oil pipelines in Michigan? Has the State of Michigan considered taking over authority to improve protections for our Great Lakes and other water resources?
Under federal law, states may choose different levels of involvement in natural gas and hazardous liquid pipeline safety regulation. The State of Michigan is involved with pipeline safety of natural gas pipelines. The State, through the Michigan Public Service Commission (MPSC), conducts inspections and enforcement for intrastate natural gas pipelines as well as inspections of interstate natural gas pipelines. Because interstate pipelines cross state borders, PHMSA is still responsible for enforcement of these lines. The State does not have authority for pipeline safety associated with crude oil or hazardous liquid pipelines.
The State has considered taking over authority for oil pipelines, however, it would require a legislative process to give the state the authority to regulate such pipelines. The Michigan Legislature would need to enact a law specifically to regulate hazardous liquid pipelines within the State. Even if Michigan obtained authority for hazardous liquid pipelines, enforcement of interstate liquids pipelines still go through PHMSA, the federal regulatory agency.
The Michigan Department of Environmental Quality (MDEQ) also has authority on pipeline installation and maintenance activities under the Natural Resources Environmental Protection Act, Act 451, 1994. If the activity is in, on, or under inland lakes, streams, wetlands, or the Great Lakes bottomlands, permits are required from the Water Resources Division.
Does the Michigan Public Service Commission look at alternatives to avoid water crossing when issuing permits for new oil pipelines?
The Michigan Public Service Commission (MPSC) approves construction of new petroleum pipelines in Michigan under Act 16 of 1929. Under this law, there is no requirement for MPSC to avoid water crossings. The only provision included is that “[a] pipeline company shall make a good-faith effort to minimize the physical impact and economic damage that result from the construction and repair of a pipeline.”
Has Enbridge obtained authorization from MDEQ under Part 325, Great Lakes Submerged Lands Act, for placement and use of Line 5?
In not, will you and when?The pipeline was approved and constructed in 1953, which pre-dated Part 325, Michigan’s Great Lakes Submerged Lands Act. The pipeline was authorized under Public Act 10 by the Michigan Department of Conservation, which predated both the MDEQ and the Michigan Department of Natural Resources. Currently, the Michigan Department of Natural Resources holds and oversees the 1953 easement.
The following questions were submitted in advance of the Northern Michigan Pipeline Symposium. Answers below were compiled from a number of sources including the presentations and panel question and answer session at the symposium as well as Tip of the Mitt Watershed Council research. We will continue to seek answers to other questions that were submitted, but are not answered below.
What governmental agencies regulate pipelines?Pipelines are regulated by a number of federal, state, and local government agencies:
- Pipeline and Hazardous Materials Safety Administration (PHMSA) – responsible for developing and enforcing pipeline safety regulations
- Federal Energy Regulatory Commission (FERC) – responsible for approving tariffs (costs of using pipeline) and siting of interstate natural gas pipelines
- Department of State (DOS) – responsible for approving pipelines that cross international borders
- National Transportation and Safety Board - investigates accidents occurring during the transport of natural gas or hazardous liquids
- Occupational Safety and Health Administration (OSHA)– responsible for worker safety
- Bureau of Land Management/Forest Service – responsible for easements on certain federal public lands
- Transportation Security Administration (TSA) - responsible for enhancing the security preparedness of the nation's hazardous liquid and natural gas pipeline systems
- EPA – responsible for regulation of hazardous materials used during construction and emergency management and responses to a pipeline accident
- Army Corps of Engineers – responsible for permitting of pipeline work in navigable waters, including the Great Lakes and connecting channels
- Department of Interior, US Fish and Wildlife Service – responsible for consultation on endangered species
- Michigan Public Service Commission (MPSC) – responsible for natural gas pipeline safety in Michigan and for approving construction, including siting and routing, of new petroleum pipelines in Michigan
- Michigan Department of Environmental Quality (MDEQ)– responsible for permitting of pipeline work in inland lakes, streams, wetlands, and the Great Lakes
What regulatory agency approves changes in pipeline capacity?
Projects of a certain size or that involve a certain number of miles of construction require notification to PHMSA. The regulatory scheme for pipeline expansions focuses on operating pressure because operating pressure is what causes stress on a pipeline. However, capacity changes can occur without ever changing the established maximum operating pressure on a pipeline system. It is not uncommon for companies to increase capacity through other means such as adding compressor stations or using drag reducing agents to decrease the friction along the pipeline wall to reduce the horsepower needed to move the product. These types of actions do not fall under the federal regulations because they are not revising the maximum operating pressure.
Enbridge submitted notification to PHMSA to increase capacity of Line 5 in May of 2012. PHMSA met with Enbridge and got a briefing on what the project entailed, formed a special inspection, and upon completion of the project, reviewed their hydrostatic testing records.
How many regulatory staff are there to monitor safety of pipelines across the country and, specifically, how many for Michigan?
The Pipeline and Hazardous Materials Safety Administration (PHMSA) is authorized for 140 inspection and enforcement personnel nationwide and 25 of those are located within the Central Region, which is responsible for pipeline safety in Michigan.
The State of Michigan also has a role with pipeline safety of natural gas pipelines. The State, through the Michigan Public Service Commission (MPSC), conducts inspections and enforcement for intrastate natural gas pipelines as well as inspections of interstate natural gas pipelines. Because interstate pipelines cross state borders, PHMSA is still responsible for enforcement of these lines. The Michigan Public Service Commission currently has 8 full time engineers in the state dedicated to pipeline inspections for natural gas pipelines.
Why does the State not have authority over oil pipelines in Michigan? Has the State of Michigan considered taking over authority to improve protections for our Great Lakes and other water resources?
Under federal law, states may choose different levels of involvement in natural gas and hazardous liquid pipeline safety regulation. The State of Michigan is involved with pipeline safety of natural gas pipelines. The State, through the Michigan Public Service Commission (MPSC), conducts inspections and enforcement for intrastate natural gas pipelines as well as inspections of interstate natural gas pipelines. Because interstate pipelines cross state borders, PHMSA is still responsible for enforcement of these lines. The State does not have authority for pipeline safety associated with crude oil or hazardous liquid pipelines.
The State has considered taking over authority for oil pipelines, however, it would require a legislative process to give the state the authority to regulate such pipelines. The Michigan Legislature would need to enact a law specifically to regulate hazardous liquid pipelines within the State. Even if Michigan obtained authority for hazardous liquid pipelines, enforcement of interstate liquids pipelines still go through PHMSA, the federal regulatory agency.
The Michigan Department of Environmental Quality (MDEQ) also has authority on pipeline installation and maintenance activities under the Natural Resources Environmental Protection Act, Act 451, 1994. If the activity is in, on, or under inland lakes, streams, wetlands, or the Great Lakes bottomlands, permits are required from the Water Resources Division.
Does the Michigan Public Service Commission look at alternatives to avoid water crossing when issuing permits for new oil pipelines?
The Michigan Public Service Commission (MPSC) approves construction of new petroleum pipelines in Michigan under Act 16 of 1929. Under this law, there is no requirement for MPSC to avoid water crossings. The only provision included is that “[a] pipeline company shall make a good-faith effort to minimize the physical impact and economic damage that result from the construction and repair of a pipeline.”
Has Enbridge obtained authorization from MDEQ under Part 325, Great Lakes Submerged Lands Act, for placement and use of Line 5?
In not, will you and when?The pipeline was approved and constructed in 1953, which pre-dated Part 325, Michigan’s Great Lakes Submerged Lands Act. The pipeline was authorized under Public Act 10 by the Michigan Department of Conservation, which predated both the MDEQ and the Michigan Department of Natural Resources. Currently, the Michigan Department of Natural Resources holds and oversees the 1953 easement.
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What support structures are required for the portion of pipeline on the lake bottom? Do we know if the pipeline is adequately supported and what, if anything, is being done to improve the condition of the pipeline and the underwater support system?The 1953 Easement between the State of Michigan and Enbridge requires support structures for the pipelines in the Straits of Mackinac every 75 feet. Enbridge evaluates the support system through external inspections conducted by remote operated vehicles (ROV). The ROV inspections are conducted every two years to identify spans, anchors, and support structures. Pipeline support comes from a variety of means such as grout, sand bags, and a screw type of anchor. Beginning in 2002-2003, Enbridge started using a screw anchor support system, as show on the image to the right. Enbridge is conducting an inspection in 2014 and will update the support structures as deemed necessary.
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Who holds a permit to drill support structures on the bottom of the Straits of Mackinac?
Enbridge Pipelines (Lakehead), L.L.C. currently has a permit to drill support structures in the Straits of Mackinac. The permit was issued in 2010 by the Michigan Department of Environmental Quality (MDEQ) and U.S. Army Corps of Engineers (USACE). In April 2014, Enbridge Pipelines (Lakehead), L.L.C. submitted a joint permit application to MDEQ and USACE to perform a visual inspection of the existing 20-inch pipelines beneath the Straits of Mackinac along with installation of support anchoring structures.
How much insurance does Enbridge provide to cover indemnity and does it cover failures of equipment and human error?
The 1953 Easement between the State of Michigan and Enbridge requires a “Comprehensive Bodily Injury and Property Damage Liability policy, bond, or surety, in form and substance acceptable to [the State] in the sum of at least One Million Dollars ($1,000,000.00).”
Please explain the meaning of the phrase "Public Trust", and how it relates to water resources such as the Great Lakes.
The Public Trust Doctrine holds that certain types of property should be protected for the public good. In place since the Roman times, and embraced by English forbears, the Public Trust means “The perpetual duty of the state to secure to its people the prevention of pollution, impairment, or destruction of its natural resources, and the rights of navigation, fishing, hunting, and use of its lands and water for public purposes. " This means the State must manage and protect the Great Lakes and other resources in the public trust.
Why are automatic or remote shutoff valves not required to be installed at all water crossings? Is this even considered to be a best management practice?
Valves are required for new hazardous liquid pipelines crossing water bodies greater than 100 feet. However, the valves do not need to be automatic or remote controlled. From a practical standpoint, new pipelines are typically installed with remote controlled valves.
The Pipeline Safety, Regulatory Certainty, and Job Creation Act of 2011 included a requirement that PHMSA issue regulations requiring the use of automatic or remote-control shut-off valves on new transmission pipelines, if feasible. A study was conducted on the use of valves and if they minimize impacts associated with a spill. PHMSA anticipates progressing with a rulemaking related to automatic or remote-control shut-off valve installation and use on hazardous liquid and gas transmission pipelines in the future.
What commodities are transported through Line 5 and where are they transported to?
The movement through Line 5 consists of natural gas liquids batched with various light products including light crude oil and condensates. These light crudes and natural gas liquids are transported to multiple Great Lakes refineries.
Are products from the oil sands in Canada transported through Line 5?
Yes, synthetic crude from oil sand deposits in the Western Canada Sedimentary Basin are transported through Line 5. However, this synthetic crude is different from the diluted bitumen (dilbit) or heavy oil sands crude that spilled into the Kalamazoo River near Marshall, Michigan.
What is synthetic crude, how does is differ from diluted bitumen, or dilbit, and can synthetic crude sink if spilled?
Synthetic crude is partially refined crude oil that is obtained from oil shale and tar sands. Synthetic crude is upgraded through a chemical process, as opposed to diluted bitumen, which is simply a blend of bitumen and a diluent. Synthetic crude exhibits properties similar to conventional light or medium crude oils. It has a specific gravity significantly less than water, so it would generally float if spilled. However, all crude oil can sink under certain conditions. (See the question below “What determines if oil sinks once spilled into the environment?”)
Will diluted bitumen be transported through Line 5?
Diluted bitumen (dilbit) is not transported through Line 5 at this time and there are currently no plans to transport dilbit through Line 5.
What is the permitting process that would enable Enbridge to pump diluted bitumen from the oil sands through Line 5?
Diluted bitumen falls under the federal definition of crude oil. Therefore, there is no permitting process for Enbridge to start transporting diluted bitumen through Line 5. According to Enbridge, modifications would need to be made to the pipeline system in order to safely transport diluted bitumen through Line 5.
Are provisions being made to ensure that Line is able to safely transport diluted bitumen from the oils sands in Canada?
Diluted bitumen (dilbit) is not transported through Line 5 at this time and there are currently no plans to transport dilbit through Line 5. According to Enbridge, modifications would need to be made to the pipeline system in order to safely transport diluted bitumen through Line 5.
What is the notification process to the public if Enbridge decides to start transporting diluted bitumen through Line 5?
There are no requirements for the public to be notified of changes to commodities transported in a pipeline. Diluted bitumen falls under the federal definition of crude oil.
What determines if oil sinks once spilled into the environment?
The physical properties of oil, along with the environmental and situational circumstances, determine how oil behaves in the environment, how it travels, how it changes and transforms, and, therefore, how it is recovered and how much impact and damage it has. For example, weather conditions and water temperature greatly influence the behavior of oil and refined petroleum products in the environment. Natural processes that may act to reduce the severity of an oil spill or accelerate the decomposition of spilled oil are always at work in the aquatic environment. These natural processes include weathering, evaporation, oxidation, biodegradation, and emulsification.
Enbridge Pipelines (Lakehead), L.L.C. currently has a permit to drill support structures in the Straits of Mackinac. The permit was issued in 2010 by the Michigan Department of Environmental Quality (MDEQ) and U.S. Army Corps of Engineers (USACE). In April 2014, Enbridge Pipelines (Lakehead), L.L.C. submitted a joint permit application to MDEQ and USACE to perform a visual inspection of the existing 20-inch pipelines beneath the Straits of Mackinac along with installation of support anchoring structures.
How much insurance does Enbridge provide to cover indemnity and does it cover failures of equipment and human error?
The 1953 Easement between the State of Michigan and Enbridge requires a “Comprehensive Bodily Injury and Property Damage Liability policy, bond, or surety, in form and substance acceptable to [the State] in the sum of at least One Million Dollars ($1,000,000.00).”
Please explain the meaning of the phrase "Public Trust", and how it relates to water resources such as the Great Lakes.
The Public Trust Doctrine holds that certain types of property should be protected for the public good. In place since the Roman times, and embraced by English forbears, the Public Trust means “The perpetual duty of the state to secure to its people the prevention of pollution, impairment, or destruction of its natural resources, and the rights of navigation, fishing, hunting, and use of its lands and water for public purposes. " This means the State must manage and protect the Great Lakes and other resources in the public trust.
Why are automatic or remote shutoff valves not required to be installed at all water crossings? Is this even considered to be a best management practice?
Valves are required for new hazardous liquid pipelines crossing water bodies greater than 100 feet. However, the valves do not need to be automatic or remote controlled. From a practical standpoint, new pipelines are typically installed with remote controlled valves.
The Pipeline Safety, Regulatory Certainty, and Job Creation Act of 2011 included a requirement that PHMSA issue regulations requiring the use of automatic or remote-control shut-off valves on new transmission pipelines, if feasible. A study was conducted on the use of valves and if they minimize impacts associated with a spill. PHMSA anticipates progressing with a rulemaking related to automatic or remote-control shut-off valve installation and use on hazardous liquid and gas transmission pipelines in the future.
What commodities are transported through Line 5 and where are they transported to?
The movement through Line 5 consists of natural gas liquids batched with various light products including light crude oil and condensates. These light crudes and natural gas liquids are transported to multiple Great Lakes refineries.
Are products from the oil sands in Canada transported through Line 5?
Yes, synthetic crude from oil sand deposits in the Western Canada Sedimentary Basin are transported through Line 5. However, this synthetic crude is different from the diluted bitumen (dilbit) or heavy oil sands crude that spilled into the Kalamazoo River near Marshall, Michigan.
What is synthetic crude, how does is differ from diluted bitumen, or dilbit, and can synthetic crude sink if spilled?
Synthetic crude is partially refined crude oil that is obtained from oil shale and tar sands. Synthetic crude is upgraded through a chemical process, as opposed to diluted bitumen, which is simply a blend of bitumen and a diluent. Synthetic crude exhibits properties similar to conventional light or medium crude oils. It has a specific gravity significantly less than water, so it would generally float if spilled. However, all crude oil can sink under certain conditions. (See the question below “What determines if oil sinks once spilled into the environment?”)
Will diluted bitumen be transported through Line 5?
Diluted bitumen (dilbit) is not transported through Line 5 at this time and there are currently no plans to transport dilbit through Line 5.
What is the permitting process that would enable Enbridge to pump diluted bitumen from the oil sands through Line 5?
Diluted bitumen falls under the federal definition of crude oil. Therefore, there is no permitting process for Enbridge to start transporting diluted bitumen through Line 5. According to Enbridge, modifications would need to be made to the pipeline system in order to safely transport diluted bitumen through Line 5.
Are provisions being made to ensure that Line is able to safely transport diluted bitumen from the oils sands in Canada?
Diluted bitumen (dilbit) is not transported through Line 5 at this time and there are currently no plans to transport dilbit through Line 5. According to Enbridge, modifications would need to be made to the pipeline system in order to safely transport diluted bitumen through Line 5.
What is the notification process to the public if Enbridge decides to start transporting diluted bitumen through Line 5?
There are no requirements for the public to be notified of changes to commodities transported in a pipeline. Diluted bitumen falls under the federal definition of crude oil.
What determines if oil sinks once spilled into the environment?
The physical properties of oil, along with the environmental and situational circumstances, determine how oil behaves in the environment, how it travels, how it changes and transforms, and, therefore, how it is recovered and how much impact and damage it has. For example, weather conditions and water temperature greatly influence the behavior of oil and refined petroleum products in the environment. Natural processes that may act to reduce the severity of an oil spill or accelerate the decomposition of spilled oil are always at work in the aquatic environment. These natural processes include weathering, evaporation, oxidation, biodegradation, and emulsification.
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The figure at right shows the weathering processes affecting oil spills:
Adsorption (sedimentation): The process by which one substance is attracted to and adheres to the surface of another substance without actually penetrating its internal structure. Biodegradation: The degradation of substances resulting from their use as food energy sources by certain micro-organisms including bacteria, fungi, and yeasts. Dispersion: The distribution of spilled oil into the upper layers of the water column by natural wave action or application of chemical dispersants. Dissolution: The act or process of dissolving one substance in another. Emulsification: The process whereby one liquid is dispersed into another liquid in the form of small droplets. Evaporation: The process whereby any substance is converted from a liquid state to become part of the surrounding atmosphere in the form of a vapor. Photo Oxidation: Sunlight-promoted chemical reaction of oxygen in the air and oil. |
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What is the current maximum operating pressure of Line 5?
The current maximum operating pressure of Line 5 is 600 pounds per square inch (psi). Line 5 has been pressure tested at 1,700 psi and is generally operated around 200 psi, with a daily range of 0-300 psi.
What type of external coating was used on Line 5?
The external coating used on Line 5 is coal tar enamel. Additional coatings that have been used on Line 5 during maintenance and repair include Tape Coat 20, Bituminous Tape, DensoTape, and fusion bonded epoxy is used for new pipeline areas.
What is the current capacity and are there projected capacity increases for Line 5?
Current capacity of Line 5 is 540,000 barrels per day, which is equal to 22.7 million gallons per day. This capacity includes a 10% capacity increase that was completed in 2013.
What is the expected life of a pipeline like Line 5? How is this determined and are the supporting engineering studies available?
The longevity of a pipeline is determined by the condition, not the age. This includes the design, construction materials, operation, and maintenance of the pipeline. The steel that the pipelines are constructed of do not age and the strength does not change unless there are issues with corrosion. According to pipeline operators and regulatory agencies, pipelines will not wear out if they are maintained properly.
What is Enbridge’s safety record?
According to the Enbridge 2013 Corporate Social Responsibility Report, Enbridge had a total of 85 reportable spills in 2012 totaling approximately 10,224 barrels (bbls) or 429,408 gallons. The spills are broken down as follows—Liquids Pipelines: 427,476 gallons; Gas Transportation: 46 bbls; Gas Distribution: 0 bbls. In addition, Gas Transportation had one gas release totaling 4.25 million standard cubic feet (MMSCF).
Of the total commodity (liquids) spills:
How is the structural integrity of pipelines maintained over many years in operation?
There are a number of components that contribute to safe operation of pipelines, including engineering design, materials used, corrosion control through coating and cathodic protection, integrity management, control center operations, and monitoring.
How often is Line 5 monitored and inspected?
Enbridge conducts aerial patrols of the pipelines at least 26 times per year and more, if warranted.
Enbridge conducts external inspections of the pipe segment in the Straits of Mackinac on a biannual basis; doing a full inspection of the crossing every two years. Enbridge uses remote operated vehicles for these inspections and is working with Michigan Tech to develop an autonomous underwater vehicle to traverse the pipeline and get good quality data on spans, anchors, and support structures along the pipelines.
Internal inspections are conducted approximately every 3-5 years. See the question below for information on the frequency of in-line inspections for the portion of Line 5 located in the Straits of Mackinac.
How frequently are in-line inspection technologies used to monitor Line 5 for metal loss, cracking, and geometry/displacement?According to a letter from PHMSA in response to an inquiry by U.S. Senators Debbie Stabenow (D-MI), Carl Levin (D-MI) and Dick Durbin (D-IL), the following integrity tests have been conducted on the Straits of Mackinac pipeline crossings using in-line inspection tools:
East loop of Mackinac Strait Line 5 crossing:
How safety have they been improved after the pipeline failure in Marshall?
Enbridge has been working on many areas since the incident in Marshall, Michigan to improve safety and operational reliability of the pipeline system. Improvements since 2010 have occurred in the areas of pipeline and facility integrity, leak detection, pipeline and control center operations, public awareness, emergency response, and instituting a culture of safety. Enbridge has conducted hundreds of in-line inspections in the various pipeline segments which drove out thousands of integrity digs for full assessment of pipeline integrity and repairs, as needed. Enbridge has developed an entire department dedicated to leak detection. Control center operations have seen tremendous change including a new facility, development of new procedures for control center operators and how they operate the line, new personnel with enhanced oversight and training, and a new accountability system. Public awareness efforts have been increased to make sure people know where pipelines are, what commodities they transport, and what to do in the event of a leak or rupture. Enbridge has created an Enbridge-wide emergency response team, making sure members throughout the various departments are trained in incident command system standards. Enbridge has also made a $50 million investment over the last 2 years in emergency response equipment.
What changes have been made specifically to the in-line inspection programs for the Enbridge system since the failure of Line 6B in Marshall, Michigan?
Since the incident in Marshall, Enbridge has spent 4.4 billion dollars to improve integrity and operational reliability programs. Pipeline and facility integrity has been improved by developing a comprehensive plan to evaluate all the pipelines within their system. This includes conducting hundreds of inspection runs through the pipes, identifying any anomalies, and conducting thousands of integrity digs for further analysis and repair as needed. The integrity dig program was also taken over by Major Products Division, who has hired staff and contractors to increase the number of digs being done.
When was the last visual inspection of the pipeline been done?
Visual inspections of Line 5 are conducted every two years and the last visual inspection was conducted in 2012.
How does Enbridge monitor welds and how frequently?Line 5 in the Straits of Mackinac is a seamless pipe, which means there are no longitudinal seams running the length of the pipe joints. While there are no seams on this segment of pipeline, there are welding joints that are inspected. In 2014, Enbridge will be monitoring the welds using a tether tool through the segments to look at each pipe joint from the interior of the pipe.
Will an inspection by an independent, non-biased contractor who is approved by all parties involved be done?
An independent inspection is not required under federal law. However, Tip of the Mitt Watershed Council is hoping to obtain copies of recent in-line inspections so we can have an independent, third-party evaluate the results.
PHMSA issued a Corrective Action Order (CAO) in 2012 for the Enbridge Lakehead Pipeline System following a failure on Line 14 near Grand Marsh, Wisconsin. What is the progress on that COA and how did expansion occur on Line 5, which is part of the Lakehead System, when a corrective action order is in place?
The CAO required Enbridge to submit a written plan including timelines for specific actions to improve the safety record of the Lakehead System. Portions of that plan have been completed and some are currently underway. Click below to access the CAO documents:
It is important to note that changing capacity does affect emergency response planning because facility response plans are based on worst-case discharges and capacity increases will increase the worst case discharge potential.
What lessons were learned from the spill in Marshall, Michigan?
PHMSA, the federal agency responsible for pipeline safety, issued an advisory bulletin in April outlying lessons learned from the Marshall spill. (DOCUMENT 6) It identifies deficiencies found in the investigation and recommended that pipeline operators review their own practices and modify, if necessary. The bulletin covers deficiencies that contributed to the release of oil into the Kalamazoo River, including problems with integrity management programs, control room operations, leak detection, and public awareness. The bulletin encouraged pipeline owners and operators to do the following: review Integrity Management programs for similar deficiencies and to take corrective action; train control room staff as teams to recognize and respond to emergencies or unexpected conditions; evaluate leak detection capabilities to ensure adequate leak detection coverage during transient operations and assess the performance of their leak detection systems following a product release to identify and implement improvements as appropriate; and to review the effectiveness of public awareness programs and whether local emergency response teams are adequately prepared to identify and respond to early indications of ruptures.
Rulemakings are also underway as part of Pipeline Safety, Regulatory Certainty, and Job Creation Act of 2011 pertaining to leak detection regulations and remote controlled/automatic shut off valves. PHMSA issued control room management and operations regulations to address fatigue and alarm management. PHMSA is also looking at the Integrity Management program requiring companies to have performance measures with meaningful metrics that will allow companies to evaluate whether their Integrity Management program is effective or not.
According to EPA, the lack of public awareness was a major lesson. Delays in reporting and notification of the release and the response time allowed the oil to travel over 2 miles. In Marshall, there was a low level of community awareness with both the public and first responders not aware the pipeline even existed. EPA learned that is important to get submerged oil containment in as soon as possible. The use of conventional technologies, such as booming, skimming, vacuuming, and excavation, recovered approximately 760,000 gallons of oil in first few weeks. Sinking occurred progressively as oil weathered over the course of days and, ultimately, the response and cleanup became about submerged oil. Another lesson is the need for science and research on submerged oil. There are studies underway to predict how submerged oil behaves in a spill, but it took the spill in Marshall to prompt those studies.
Not only are the lessons learned vitally important, but those involved also need to learn and share experiences with other pipeline operators and integrate the lessons learned into the planning phase rather than the reactive phase.
Is it possible to enhance protections with installation of secondary containment?
Enbridge is evaluating potential secondary containment options for the Line 5 pipeline segment in the Straits of Mackinac.
Are there any plans to remove or replace Line 5?
No, there are no current plans to remove or replace the pipeline.
What plans are in place to address a spill on Line 5?
Multiple facility response plans have been developed for Line 5, including plans developed by the USCG, EPA, MDEQ, and Enbridge.
An Integrated Contingency Plan is the core emergency response plan. Releases of oil and hazardous materials are regulated separately under the Oil Pollution Act of 1990 (OPA) and the Comprehensive Environmental Response, Compensation, and Liability Act of 1980 (CERCLA). Both mandate the development of contingency plans, and there is significant overlap in the type and scope of information required to do so. In order to minimize confusion and maximize resources, the two contingency plans are combined as an Integrated Contingency Plan (ICP).
Enbridge Superior Region Response Zone Plan
There are also Area Contingency Plans that are developed to enhance the contingency planning of federal, state, and local agencies; assure preplanning of joint response efforts; and expedite decisions for the use of dispersants and other substances or mitigating devices.
Northern Michigan Subarea Contingency Plan
Tactical plans are intended to provide significant pre-planning information to a response in areas of high consequence. Tactical plans exist for the Straits of Mackinac, Indian River, and Pigeon River areas.
Has anyone generated a 3-dimensional hydrodynamic flow model of the Straits of Mackinac that has been used to predict dispersion patterns from a range of oil spill scenarios? If not, why not?Yes, 3-D models for dispersion factor into Enbridge's tactical response document.
The National Oceanic and Atmospheric Administration (NOAA) has also developed trajectory models for use by the United States Coast Guard (USCG) in their response plans, although they are not shared for security reasons.
The current maximum operating pressure of Line 5 is 600 pounds per square inch (psi). Line 5 has been pressure tested at 1,700 psi and is generally operated around 200 psi, with a daily range of 0-300 psi.
What type of external coating was used on Line 5?
The external coating used on Line 5 is coal tar enamel. Additional coatings that have been used on Line 5 during maintenance and repair include Tape Coat 20, Bituminous Tape, DensoTape, and fusion bonded epoxy is used for new pipeline areas.
What is the current capacity and are there projected capacity increases for Line 5?
Current capacity of Line 5 is 540,000 barrels per day, which is equal to 22.7 million gallons per day. This capacity includes a 10% capacity increase that was completed in 2013.
What is the expected life of a pipeline like Line 5? How is this determined and are the supporting engineering studies available?
The longevity of a pipeline is determined by the condition, not the age. This includes the design, construction materials, operation, and maintenance of the pipeline. The steel that the pipelines are constructed of do not age and the strength does not change unless there are issues with corrosion. According to pipeline operators and regulatory agencies, pipelines will not wear out if they are maintained properly.
What is Enbridge’s safety record?
According to the Enbridge 2013 Corporate Social Responsibility Report, Enbridge had a total of 85 reportable spills in 2012 totaling approximately 10,224 barrels (bbls) or 429,408 gallons. The spills are broken down as follows—Liquids Pipelines: 427,476 gallons; Gas Transportation: 46 bbls; Gas Distribution: 0 bbls. In addition, Gas Transportation had one gas release totaling 4.25 million standard cubic feet (MMSCF).
Of the total commodity (liquids) spills:
- 68 of them or approximately 80 percent had a volume of 42 gallons or less
- 66 of them or approximately 78 percent occurred at Enbridge facilities
- 19 of them or approximately 22 percent occurred on Enbridge rights-of-way or not located on Enbridge property
How is the structural integrity of pipelines maintained over many years in operation?
There are a number of components that contribute to safe operation of pipelines, including engineering design, materials used, corrosion control through coating and cathodic protection, integrity management, control center operations, and monitoring.
How often is Line 5 monitored and inspected?
Enbridge conducts aerial patrols of the pipelines at least 26 times per year and more, if warranted.
Enbridge conducts external inspections of the pipe segment in the Straits of Mackinac on a biannual basis; doing a full inspection of the crossing every two years. Enbridge uses remote operated vehicles for these inspections and is working with Michigan Tech to develop an autonomous underwater vehicle to traverse the pipeline and get good quality data on spans, anchors, and support structures along the pipelines.
Internal inspections are conducted approximately every 3-5 years. See the question below for information on the frequency of in-line inspections for the portion of Line 5 located in the Straits of Mackinac.
How frequently are in-line inspection technologies used to monitor Line 5 for metal loss, cracking, and geometry/displacement?According to a letter from PHMSA in response to an inquiry by U.S. Senators Debbie Stabenow (D-MI), Carl Levin (D-MI) and Dick Durbin (D-IL), the following integrity tests have been conducted on the Straits of Mackinac pipeline crossings using in-line inspection tools:
East loop of Mackinac Strait Line 5 crossing:
- 1998 metal loss survey
- 2003 metal loss survey
- 2003 geometry inspection
- 2005 geometry inspection
- 2008 metal loss survey
- 2008 geometry inspection
- 2013 metal loss survey
- 2013 geometry inspection
- 1998 metal loss survey
- 2003 metal loss survey
- 2005 geometry inspection
- 2008 metal loss survey
- 2008 geometry inspection
- 2012 geometry inspection
- 2013 metal loss survey
- 2013 geometry inspection
How safety have they been improved after the pipeline failure in Marshall?
Enbridge has been working on many areas since the incident in Marshall, Michigan to improve safety and operational reliability of the pipeline system. Improvements since 2010 have occurred in the areas of pipeline and facility integrity, leak detection, pipeline and control center operations, public awareness, emergency response, and instituting a culture of safety. Enbridge has conducted hundreds of in-line inspections in the various pipeline segments which drove out thousands of integrity digs for full assessment of pipeline integrity and repairs, as needed. Enbridge has developed an entire department dedicated to leak detection. Control center operations have seen tremendous change including a new facility, development of new procedures for control center operators and how they operate the line, new personnel with enhanced oversight and training, and a new accountability system. Public awareness efforts have been increased to make sure people know where pipelines are, what commodities they transport, and what to do in the event of a leak or rupture. Enbridge has created an Enbridge-wide emergency response team, making sure members throughout the various departments are trained in incident command system standards. Enbridge has also made a $50 million investment over the last 2 years in emergency response equipment.
What changes have been made specifically to the in-line inspection programs for the Enbridge system since the failure of Line 6B in Marshall, Michigan?
Since the incident in Marshall, Enbridge has spent 4.4 billion dollars to improve integrity and operational reliability programs. Pipeline and facility integrity has been improved by developing a comprehensive plan to evaluate all the pipelines within their system. This includes conducting hundreds of inspection runs through the pipes, identifying any anomalies, and conducting thousands of integrity digs for further analysis and repair as needed. The integrity dig program was also taken over by Major Products Division, who has hired staff and contractors to increase the number of digs being done.
When was the last visual inspection of the pipeline been done?
Visual inspections of Line 5 are conducted every two years and the last visual inspection was conducted in 2012.
How does Enbridge monitor welds and how frequently?Line 5 in the Straits of Mackinac is a seamless pipe, which means there are no longitudinal seams running the length of the pipe joints. While there are no seams on this segment of pipeline, there are welding joints that are inspected. In 2014, Enbridge will be monitoring the welds using a tether tool through the segments to look at each pipe joint from the interior of the pipe.
Will an inspection by an independent, non-biased contractor who is approved by all parties involved be done?
An independent inspection is not required under federal law. However, Tip of the Mitt Watershed Council is hoping to obtain copies of recent in-line inspections so we can have an independent, third-party evaluate the results.
PHMSA issued a Corrective Action Order (CAO) in 2012 for the Enbridge Lakehead Pipeline System following a failure on Line 14 near Grand Marsh, Wisconsin. What is the progress on that COA and how did expansion occur on Line 5, which is part of the Lakehead System, when a corrective action order is in place?
The CAO required Enbridge to submit a written plan including timelines for specific actions to improve the safety record of the Lakehead System. Portions of that plan have been completed and some are currently underway. Click below to access the CAO documents:
- Corrective Action Order
- Notice of Proposed Amendment to Corrective Action Order
- Final Corrective Action Order
It is important to note that changing capacity does affect emergency response planning because facility response plans are based on worst-case discharges and capacity increases will increase the worst case discharge potential.
What lessons were learned from the spill in Marshall, Michigan?
PHMSA, the federal agency responsible for pipeline safety, issued an advisory bulletin in April outlying lessons learned from the Marshall spill. (DOCUMENT 6) It identifies deficiencies found in the investigation and recommended that pipeline operators review their own practices and modify, if necessary. The bulletin covers deficiencies that contributed to the release of oil into the Kalamazoo River, including problems with integrity management programs, control room operations, leak detection, and public awareness. The bulletin encouraged pipeline owners and operators to do the following: review Integrity Management programs for similar deficiencies and to take corrective action; train control room staff as teams to recognize and respond to emergencies or unexpected conditions; evaluate leak detection capabilities to ensure adequate leak detection coverage during transient operations and assess the performance of their leak detection systems following a product release to identify and implement improvements as appropriate; and to review the effectiveness of public awareness programs and whether local emergency response teams are adequately prepared to identify and respond to early indications of ruptures.
Rulemakings are also underway as part of Pipeline Safety, Regulatory Certainty, and Job Creation Act of 2011 pertaining to leak detection regulations and remote controlled/automatic shut off valves. PHMSA issued control room management and operations regulations to address fatigue and alarm management. PHMSA is also looking at the Integrity Management program requiring companies to have performance measures with meaningful metrics that will allow companies to evaluate whether their Integrity Management program is effective or not.
According to EPA, the lack of public awareness was a major lesson. Delays in reporting and notification of the release and the response time allowed the oil to travel over 2 miles. In Marshall, there was a low level of community awareness with both the public and first responders not aware the pipeline even existed. EPA learned that is important to get submerged oil containment in as soon as possible. The use of conventional technologies, such as booming, skimming, vacuuming, and excavation, recovered approximately 760,000 gallons of oil in first few weeks. Sinking occurred progressively as oil weathered over the course of days and, ultimately, the response and cleanup became about submerged oil. Another lesson is the need for science and research on submerged oil. There are studies underway to predict how submerged oil behaves in a spill, but it took the spill in Marshall to prompt those studies.
Not only are the lessons learned vitally important, but those involved also need to learn and share experiences with other pipeline operators and integrate the lessons learned into the planning phase rather than the reactive phase.
Is it possible to enhance protections with installation of secondary containment?
Enbridge is evaluating potential secondary containment options for the Line 5 pipeline segment in the Straits of Mackinac.
Are there any plans to remove or replace Line 5?
No, there are no current plans to remove or replace the pipeline.
What plans are in place to address a spill on Line 5?
Multiple facility response plans have been developed for Line 5, including plans developed by the USCG, EPA, MDEQ, and Enbridge.
An Integrated Contingency Plan is the core emergency response plan. Releases of oil and hazardous materials are regulated separately under the Oil Pollution Act of 1990 (OPA) and the Comprehensive Environmental Response, Compensation, and Liability Act of 1980 (CERCLA). Both mandate the development of contingency plans, and there is significant overlap in the type and scope of information required to do so. In order to minimize confusion and maximize resources, the two contingency plans are combined as an Integrated Contingency Plan (ICP).
Enbridge Superior Region Response Zone Plan
There are also Area Contingency Plans that are developed to enhance the contingency planning of federal, state, and local agencies; assure preplanning of joint response efforts; and expedite decisions for the use of dispersants and other substances or mitigating devices.
Northern Michigan Subarea Contingency Plan
Tactical plans are intended to provide significant pre-planning information to a response in areas of high consequence. Tactical plans exist for the Straits of Mackinac, Indian River, and Pigeon River areas.
Has anyone generated a 3-dimensional hydrodynamic flow model of the Straits of Mackinac that has been used to predict dispersion patterns from a range of oil spill scenarios? If not, why not?Yes, 3-D models for dispersion factor into Enbridge's tactical response document.
The National Oceanic and Atmospheric Administration (NOAA) has also developed trajectory models for use by the United States Coast Guard (USCG) in their response plans, although they are not shared for security reasons.
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Recently, the National Wildlife Federation and University of Michigan released a study entitled “Straits of Mackinac Contaminant Release Scenarios: Flow Visualization And Tracer Simulations.” The study simulated the release of contaminants at various locations and depths within the Straits of Mackinac. The simulations and video animation track an oil spill of 1 million gallons that would be released over a 12-hour period. The animation shows where oil would travel in the 20 days following a spill.
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How are pipeline leaks detected?
There are several ways for pipeline operators to detect pipeline leaks. Leaks can be detected by control center operators who are monitoring operations on a 24 hour, 7 day a week basis, watching real-time data such as pressure. There is also a mass balance system which measures flow through the line and compares the flow in and flow out. Any discrepancy between the two sends a trigger to the control room operator to shut down the pipeline. Leaks can also be detected by automatic valves that monitor pressure reductions and automatically go into a closed cycle which shut the pipeline down when there is a drop in pressure. Aerial patrols and flying pipeline right-of way is another way to identify leaks, in addition to public notification of an odor or another sign of a leak.
How long will it take to completely shut down the pipeline once a leak is detected?
Enbridge claims a line can be shut down very quickly in the event of a leak, On a 30 inch diameter pipeline, the valve is cycling shut in about 3 minutes and on a 20 inch diameter pipeline, it takes approximately 2 minutes to close the system.
Should a leak occur in the portion of pipeline in the Straits during winter with significant ice, how would it be discovered?
The majority of Enbridge’s 50,000 miles of pipeline are buried without visual access. Therefore, pipeline leak detection methods are focused on pipelines that cannot be seen. A leak in ice conditions would be detected using the same methods that are used to detect typical leaks in buried pipelines. This includes evaluation of a mass balance system looking at what is going into the pipe versus what is coming out. Leaks can also be detected by changes in operating pressures and constant surveillance by the Control Center operations. On the Straits of Mackinac, Enbridge is also able to monitor the pressure in the pipeline segment from valve to valve in static conditions, when line is shut down. Any bleed off of pressure is an indicator that something is wrong.
How would the public be notified if a leak or break in the pipeline was detected and how quickly?
It would depend on extent of leak or break. For smaller leaks that do not pose a threat to public health and safety, the public will likely not be notified. However, the Tri-County Office of Emergency Management will issue alerts if there is a large-scale event. This could occur through the traditional emergency alert system (the same one that notifies you of tornados) or those residing within the counties of Charlevoix, Cheboygan, and Emmet are encouraged to sign up for *BE ALERT* notifications through our local Tri-County Office of Emergency Management. To sign up, simply go to https://bealert.smartmsg.com and select the devices that you want to receive alerts. You can enter in multiple devices so the whole family is covered. You can even add on severe thunderstorm or tornado warnings for your area. The service is free for the public to enroll.
In the event of a pipeline failure from Line 5 or any other pipeline in the region, who responds, at what response time, and where do they come from?
Realistically, how long does it take to marshal the personnel and equipment to actually start containment and cleanup of an oil spill?The process or sequence for response in the event of a pipeline failure is as follows: the pipeline operator will be there first along with local first responders such as the Office of Emergency Management, police, and fire. As this is occurring, notification is being made to other entities such as MDEQ, EPA, the U.S. Coast Guard (USCG), and to the company’s cleanup contractors which are called Oil Spill Response Organizations or OSROs. There is an OSRO, Mackinac Environmental, located right on the Straits of Mackinac in St. Ignace, which would significantly decrease response time for a spill in the Straits. All of this happens fairly quickly – in a matter of minutes - but response time ultimately depends upon many factors such as the location and ease of access.
The rest of the response depends on the size and extend of the failure. After arriving to a spill, assessment and inspection of the leak or rupture occurs. If an incident occurred in the Straits of Mackinac, it would take the USCG pollution investigators approximately 1 hour – 1 ½ hour to arrive. USCG has a 13 person Incident Command System team that would follow to start the response activities and to order in more people and resources, as deemed necessary. This could happen quickly and there could be hundreds of personnel on site within the first 24 hours.
From there, there is a tiered response where equipment and resources will be brought in as needed until enough resources are available. This process takes time. The initial response and assessment will happen right away, but assembling the equipment and appropriate teams of people can take longer. For example, it took days and days to assemble the 2,500 people and 200 excavators needed to address the spill in Marshall, Michigan.
For the Straits segment of the pipeline, EPA and USCG have questions about whether there are enough resources available to respond in a timely way or if more resources are needed. These agencies are investigating and working with the pipeline companies and response agencies to determine if we have the resources and are adequately prepared to respond to a spill in Northern Michigan. Exercises, such as the one that will occur in Indian River later this year, provide a good opportunity to look at available resources and identify if more resources are needed to appropriately respond and what specifically those needs may be.
What plans are there for shortening response time for a leak?
First, an increase in public awareness for first responders and the public in Northern Michigan is vitally important to how quickly a leak can be identified. Public awareness will minimize delays in discovering a release and the response time for local first responders.
Second, there is significant contingency planning underway in Northern Michigan. There are over 66 different agencies including various federal, state, local, tribal, academia, and industry working collaboratively to improve preparedness. This includes conducting live exercises as well as looking at specific issues that may be encountered during a spill in Northern Michigan, such as submerged or non-buoyant oil and oil and ice recovery.
Additionally, Enbridge has made modifications to operations to address the failures encountered in Marshall, Michigan which exacerbated the spill. Improvements since 2010 have occurred in the areas of pipeline and facility integrity, leak detection, pipeline and control center operations, public awareness, and emergency response.
What is the role of our local fire and police in the event of an oil spill and do they have the equipment and training to be able to respond to an emergency?
When there is a pipeline failure, the local first responders are the initial eyes, ears, and boots on the ground. The primary focus of local fire and police is public safety. The may engage in traffic control, evacuations if necessary, and other activities that ensure the public are is from harm. They will maintain the scene until the federal On-Scene Coordinator arrives to lead the cleanup efforts.
How is spill response and cleanup conducted in severe winter conditions such as thick ice cover and frigid temperatures?
There are significant challenges associated with ice recovery. In recent years, there have been a number of exercises on how to respond to leaks in ice. These oil and ice drills which tested many new techniques and types of equipment such as remote operated vehicles and autonomous vehicles to identify and find oil under the ice, infrared radar to detect oil in the water column, and “aerostat” which is a tethered blimp that allows first responders to see where oil is in ice. The techniques being used and developed in Northern Michigan are also being used in Alaska and this region is become the center of excellence for oil and ice recovery techniques. Exercises and drills will continue in the Straits region to continue to evaluate equipment - what works and what does not work - and to continue to develop and perfect techniques.
Additionally, it is very rare to have solid ice cover in the Straits of Mackinac; ice conditions are changing constantly due to currents and winds.
What cleanup and containment resources, including length of boom, are available on each side of the Straits of Mackinac and in Indian River?
There are 4,500 feet of boom total in the Straits, 400 feet of boom available in a response trailer located in Indian River, 2,000 feet in Cheboygan, 10,000 feet in Roger's City, 3,000 feet in Kalkaska, 16,000 feet in Sault Ste. Marie, 10,000 in Detroit, and multiple locations in southern Michigan and nearby states such as Indiana that have 1,000 feet or less. This is the containment boom that Marine Pollution Control, a primary Oil Spill Response Organization for Enbridge, has confirmed. More boom may be available in the region from other sources.
Which municipal drinking water systems would be affected if there were a significant spill at the Straits or elsewhere in Northern Michigan?
Water intakes are mapped on the EPA Region 5 Inland Sensitivity Atlas. The Atlas is a set of databases and maps that display potential spill sources, sensitive resources, infrastructure, and cultural information.
Due to sensitive content within the atlas, map distribution is limited to emergency responders and contingency planners. Non-sensitive data are available to the general public in GIS, MARPLOT, and database files. For product availability and distribution, contact:
U.S. Environmental Protection Agency, Region 5
Oil Planning and Response Section
77 West Jackson Blvd (SE-5J)
Chicago, IL 60604
Will the pipeline company be responsible for the cost of a spill or will the citizens of Michigan pay for the cleanup?
Under the Oil Pollution Act of 1990, the owner or operator of a facility from which oil is discharged (also known as the responsible Party) is liable for the costs associated with the containment or cleanup of the spill and any damages resulting from the spill. The EPA's first priority is to ensure that responsible parties pay to clean up their own oil releases. However, when the responsible party is unknown or refuses to pay, funds from the Oil Spill Liability Trust Fund can be used to cover removal costs or damages resulting from discharges of oil.
The primary source of revenue for the fund is a five-cents per barrel fee on imported and domestic oil. Collection of this fee ceased on December 31, 1994 due to a "sunset" provision in the law. Other revenue sources for the fund include interest on the fund, cost recovery from the parties responsible for the spills, and any fines or civil penalties collected.
The Fund can provide up to $1 billion for any one oil pollution incident, including up to $500 million for the initiation of natural resource damage assessments and claims in connection with any single incident. The main uses of Fund expenditures are:
If Enbridge, or a subsidiary, declares bankruptcy or defaults, who is liable for any cleanup?
When the responsible party is unknown or refuses to pay, funds from the Oil Spill Liability Trust Fund can be used to cover removal costs or damages resulting from discharges of oil. (See answer above)
What economic benefits does operation of pipelines by Enbridge provide to the State of Michigan?
In 2013, Enbridge paid approximately $21 million to the State of Michigan in the form of state property, sales, use, and income taxes.
Does Line 5 provide jobs for Michigan citizens? If yes, what types of jobs, how many, and are they temporary (i.e. construction/installation of pipelines) or permanent?
Enbridge employs approximately 250 employees and contractors in the state at 24 locations, with an average annual salary of $82,000.
Does the State of Michigan receive and/or use any of the products transported through Line 5 or is Line 5 just a highway to send products elsewhere?
Enbridge delivers about 2.5 million barrels per day of crude oil and liquids petroleum through their pipeline system, which accounts for more than 50% of the crude that is provided for the Great Lakes refineries in Chicago, Detroit, and Superior, Wisconsin. Additionally, the natural gas liquids (NGLs) transported through Line 5 provide propane for Wisconsin and Michigan.
What was the profit in 2013 for Enbridge?
Gross annual profit for 2013 is estimated at $5.74 billion. Financial information is available in the Enbridge 2013 Annual Report.
How is Enbridge addressing climate change and helping the nation work towards transitioning away from fossil fuels towards a clean and low carbon economy?
Enbridge is investing in a cleaner energy future. Enbridge has an emerging green energy platform, with ownership interests in about 1,800 megawatts of wind, solar, geothermal, and heat waste recovery, for a total capital investment of about $3.5 billion dollars in green energy technologies. Enbridge has also made a commitment to a neutral footprint in with respect to development. This entails producing a kilowatt of power for every kilowatt of power consumed on the pipeline right of way, providing an acre of land for every acre used in projects, and planting a tree for every tree removed as part of operations.
Can regulators force closure of a pipeline, including Line 5? If yes, under what circumstances and what is the process?
PHSMA does not approve or authorize the siting or proposed construction of a natural gas or hazardous liquid pipeline. PHMSA has issued safety regulations that apply to the design and construction of a pipeline and to its subsequent operation that it administers in conjunction with various State entities. Under certain circumstances, PHMSA has the authority to protect public safety and the environment by imposing conditions on the use of a pipeline to ensure its future integrity. If PHMSA determines that a particular pipeline facility is hazardous to life, property, or the environment, the Agency may issue an order requiring the owner or operator of the facility to take corrective action, which may include suspended or restricted use of the facility, physical inspection, testing, repair, replacement, or other appropriate action (see 49 CFR §190.233). These orders are typically terminated once the corrective actions are completed if PHMSA determines that the facility is no longer hazardous to life, property, or the environment.
What is the age of the oldest pipeline currently in operation in Michigan?
PHMSA regulations require that each pipeline operator report its mileage by decade of installation. There is some mileage in Michigan that is reported to be of unknown vintage. Based upon the data reported for known vintages, the oldest pipe still in operation in Michigan for hazardous liquids was installed during the 1930’s and for natural gas was installed prior to 1940 (the earliest reporting category is “pre-1940s”).
There are several ways for pipeline operators to detect pipeline leaks. Leaks can be detected by control center operators who are monitoring operations on a 24 hour, 7 day a week basis, watching real-time data such as pressure. There is also a mass balance system which measures flow through the line and compares the flow in and flow out. Any discrepancy between the two sends a trigger to the control room operator to shut down the pipeline. Leaks can also be detected by automatic valves that monitor pressure reductions and automatically go into a closed cycle which shut the pipeline down when there is a drop in pressure. Aerial patrols and flying pipeline right-of way is another way to identify leaks, in addition to public notification of an odor or another sign of a leak.
How long will it take to completely shut down the pipeline once a leak is detected?
Enbridge claims a line can be shut down very quickly in the event of a leak, On a 30 inch diameter pipeline, the valve is cycling shut in about 3 minutes and on a 20 inch diameter pipeline, it takes approximately 2 minutes to close the system.
Should a leak occur in the portion of pipeline in the Straits during winter with significant ice, how would it be discovered?
The majority of Enbridge’s 50,000 miles of pipeline are buried without visual access. Therefore, pipeline leak detection methods are focused on pipelines that cannot be seen. A leak in ice conditions would be detected using the same methods that are used to detect typical leaks in buried pipelines. This includes evaluation of a mass balance system looking at what is going into the pipe versus what is coming out. Leaks can also be detected by changes in operating pressures and constant surveillance by the Control Center operations. On the Straits of Mackinac, Enbridge is also able to monitor the pressure in the pipeline segment from valve to valve in static conditions, when line is shut down. Any bleed off of pressure is an indicator that something is wrong.
How would the public be notified if a leak or break in the pipeline was detected and how quickly?
It would depend on extent of leak or break. For smaller leaks that do not pose a threat to public health and safety, the public will likely not be notified. However, the Tri-County Office of Emergency Management will issue alerts if there is a large-scale event. This could occur through the traditional emergency alert system (the same one that notifies you of tornados) or those residing within the counties of Charlevoix, Cheboygan, and Emmet are encouraged to sign up for *BE ALERT* notifications through our local Tri-County Office of Emergency Management. To sign up, simply go to https://bealert.smartmsg.com and select the devices that you want to receive alerts. You can enter in multiple devices so the whole family is covered. You can even add on severe thunderstorm or tornado warnings for your area. The service is free for the public to enroll.
In the event of a pipeline failure from Line 5 or any other pipeline in the region, who responds, at what response time, and where do they come from?
Realistically, how long does it take to marshal the personnel and equipment to actually start containment and cleanup of an oil spill?The process or sequence for response in the event of a pipeline failure is as follows: the pipeline operator will be there first along with local first responders such as the Office of Emergency Management, police, and fire. As this is occurring, notification is being made to other entities such as MDEQ, EPA, the U.S. Coast Guard (USCG), and to the company’s cleanup contractors which are called Oil Spill Response Organizations or OSROs. There is an OSRO, Mackinac Environmental, located right on the Straits of Mackinac in St. Ignace, which would significantly decrease response time for a spill in the Straits. All of this happens fairly quickly – in a matter of minutes - but response time ultimately depends upon many factors such as the location and ease of access.
The rest of the response depends on the size and extend of the failure. After arriving to a spill, assessment and inspection of the leak or rupture occurs. If an incident occurred in the Straits of Mackinac, it would take the USCG pollution investigators approximately 1 hour – 1 ½ hour to arrive. USCG has a 13 person Incident Command System team that would follow to start the response activities and to order in more people and resources, as deemed necessary. This could happen quickly and there could be hundreds of personnel on site within the first 24 hours.
From there, there is a tiered response where equipment and resources will be brought in as needed until enough resources are available. This process takes time. The initial response and assessment will happen right away, but assembling the equipment and appropriate teams of people can take longer. For example, it took days and days to assemble the 2,500 people and 200 excavators needed to address the spill in Marshall, Michigan.
For the Straits segment of the pipeline, EPA and USCG have questions about whether there are enough resources available to respond in a timely way or if more resources are needed. These agencies are investigating and working with the pipeline companies and response agencies to determine if we have the resources and are adequately prepared to respond to a spill in Northern Michigan. Exercises, such as the one that will occur in Indian River later this year, provide a good opportunity to look at available resources and identify if more resources are needed to appropriately respond and what specifically those needs may be.
What plans are there for shortening response time for a leak?
First, an increase in public awareness for first responders and the public in Northern Michigan is vitally important to how quickly a leak can be identified. Public awareness will minimize delays in discovering a release and the response time for local first responders.
Second, there is significant contingency planning underway in Northern Michigan. There are over 66 different agencies including various federal, state, local, tribal, academia, and industry working collaboratively to improve preparedness. This includes conducting live exercises as well as looking at specific issues that may be encountered during a spill in Northern Michigan, such as submerged or non-buoyant oil and oil and ice recovery.
Additionally, Enbridge has made modifications to operations to address the failures encountered in Marshall, Michigan which exacerbated the spill. Improvements since 2010 have occurred in the areas of pipeline and facility integrity, leak detection, pipeline and control center operations, public awareness, and emergency response.
What is the role of our local fire and police in the event of an oil spill and do they have the equipment and training to be able to respond to an emergency?
When there is a pipeline failure, the local first responders are the initial eyes, ears, and boots on the ground. The primary focus of local fire and police is public safety. The may engage in traffic control, evacuations if necessary, and other activities that ensure the public are is from harm. They will maintain the scene until the federal On-Scene Coordinator arrives to lead the cleanup efforts.
How is spill response and cleanup conducted in severe winter conditions such as thick ice cover and frigid temperatures?
There are significant challenges associated with ice recovery. In recent years, there have been a number of exercises on how to respond to leaks in ice. These oil and ice drills which tested many new techniques and types of equipment such as remote operated vehicles and autonomous vehicles to identify and find oil under the ice, infrared radar to detect oil in the water column, and “aerostat” which is a tethered blimp that allows first responders to see where oil is in ice. The techniques being used and developed in Northern Michigan are also being used in Alaska and this region is become the center of excellence for oil and ice recovery techniques. Exercises and drills will continue in the Straits region to continue to evaluate equipment - what works and what does not work - and to continue to develop and perfect techniques.
Additionally, it is very rare to have solid ice cover in the Straits of Mackinac; ice conditions are changing constantly due to currents and winds.
What cleanup and containment resources, including length of boom, are available on each side of the Straits of Mackinac and in Indian River?
There are 4,500 feet of boom total in the Straits, 400 feet of boom available in a response trailer located in Indian River, 2,000 feet in Cheboygan, 10,000 feet in Roger's City, 3,000 feet in Kalkaska, 16,000 feet in Sault Ste. Marie, 10,000 in Detroit, and multiple locations in southern Michigan and nearby states such as Indiana that have 1,000 feet or less. This is the containment boom that Marine Pollution Control, a primary Oil Spill Response Organization for Enbridge, has confirmed. More boom may be available in the region from other sources.
Which municipal drinking water systems would be affected if there were a significant spill at the Straits or elsewhere in Northern Michigan?
Water intakes are mapped on the EPA Region 5 Inland Sensitivity Atlas. The Atlas is a set of databases and maps that display potential spill sources, sensitive resources, infrastructure, and cultural information.
Due to sensitive content within the atlas, map distribution is limited to emergency responders and contingency planners. Non-sensitive data are available to the general public in GIS, MARPLOT, and database files. For product availability and distribution, contact:
U.S. Environmental Protection Agency, Region 5
Oil Planning and Response Section
77 West Jackson Blvd (SE-5J)
Chicago, IL 60604
Will the pipeline company be responsible for the cost of a spill or will the citizens of Michigan pay for the cleanup?
Under the Oil Pollution Act of 1990, the owner or operator of a facility from which oil is discharged (also known as the responsible Party) is liable for the costs associated with the containment or cleanup of the spill and any damages resulting from the spill. The EPA's first priority is to ensure that responsible parties pay to clean up their own oil releases. However, when the responsible party is unknown or refuses to pay, funds from the Oil Spill Liability Trust Fund can be used to cover removal costs or damages resulting from discharges of oil.
The primary source of revenue for the fund is a five-cents per barrel fee on imported and domestic oil. Collection of this fee ceased on December 31, 1994 due to a "sunset" provision in the law. Other revenue sources for the fund include interest on the fund, cost recovery from the parties responsible for the spills, and any fines or civil penalties collected.
The Fund can provide up to $1 billion for any one oil pollution incident, including up to $500 million for the initiation of natural resource damage assessments and claims in connection with any single incident. The main uses of Fund expenditures are:
- State access for removal actions;
- Payments to Federal, state, and Indian tribe trustees to carry out natural resource damage assessments and restorations;
- Payment of claims for uncompensated removal costs and damages; and
- Research and development and other specific appropriations.
If Enbridge, or a subsidiary, declares bankruptcy or defaults, who is liable for any cleanup?
When the responsible party is unknown or refuses to pay, funds from the Oil Spill Liability Trust Fund can be used to cover removal costs or damages resulting from discharges of oil. (See answer above)
What economic benefits does operation of pipelines by Enbridge provide to the State of Michigan?
In 2013, Enbridge paid approximately $21 million to the State of Michigan in the form of state property, sales, use, and income taxes.
Does Line 5 provide jobs for Michigan citizens? If yes, what types of jobs, how many, and are they temporary (i.e. construction/installation of pipelines) or permanent?
Enbridge employs approximately 250 employees and contractors in the state at 24 locations, with an average annual salary of $82,000.
Does the State of Michigan receive and/or use any of the products transported through Line 5 or is Line 5 just a highway to send products elsewhere?
Enbridge delivers about 2.5 million barrels per day of crude oil and liquids petroleum through their pipeline system, which accounts for more than 50% of the crude that is provided for the Great Lakes refineries in Chicago, Detroit, and Superior, Wisconsin. Additionally, the natural gas liquids (NGLs) transported through Line 5 provide propane for Wisconsin and Michigan.
What was the profit in 2013 for Enbridge?
Gross annual profit for 2013 is estimated at $5.74 billion. Financial information is available in the Enbridge 2013 Annual Report.
How is Enbridge addressing climate change and helping the nation work towards transitioning away from fossil fuels towards a clean and low carbon economy?
Enbridge is investing in a cleaner energy future. Enbridge has an emerging green energy platform, with ownership interests in about 1,800 megawatts of wind, solar, geothermal, and heat waste recovery, for a total capital investment of about $3.5 billion dollars in green energy technologies. Enbridge has also made a commitment to a neutral footprint in with respect to development. This entails producing a kilowatt of power for every kilowatt of power consumed on the pipeline right of way, providing an acre of land for every acre used in projects, and planting a tree for every tree removed as part of operations.
Can regulators force closure of a pipeline, including Line 5? If yes, under what circumstances and what is the process?
PHSMA does not approve or authorize the siting or proposed construction of a natural gas or hazardous liquid pipeline. PHMSA has issued safety regulations that apply to the design and construction of a pipeline and to its subsequent operation that it administers in conjunction with various State entities. Under certain circumstances, PHMSA has the authority to protect public safety and the environment by imposing conditions on the use of a pipeline to ensure its future integrity. If PHMSA determines that a particular pipeline facility is hazardous to life, property, or the environment, the Agency may issue an order requiring the owner or operator of the facility to take corrective action, which may include suspended or restricted use of the facility, physical inspection, testing, repair, replacement, or other appropriate action (see 49 CFR §190.233). These orders are typically terminated once the corrective actions are completed if PHMSA determines that the facility is no longer hazardous to life, property, or the environment.
What is the age of the oldest pipeline currently in operation in Michigan?
PHMSA regulations require that each pipeline operator report its mileage by decade of installation. There is some mileage in Michigan that is reported to be of unknown vintage. Based upon the data reported for known vintages, the oldest pipe still in operation in Michigan for hazardous liquids was installed during the 1930’s and for natural gas was installed prior to 1940 (the earliest reporting category is “pre-1940s”).
