Q. What is the maximum volume that the present 36-inch
Cove Point line will handle and will a second 36-inch line double this volume?
What is the largest single pipeline that the current right-of-way would accommodate
and what would be its capacity?
A. The current Cove Point 36-inch pipeline is designed to move 1 billion standard
cubic feet of natural gas per day while maintaining customer contract requirements
for delivery along the line. The proposed 36-inch pipeline will enable Cove
Point to move an additional 800 million standard cubic feet per day while maintaining
all customer requirements for delivery along the line. Replacing the existing
pipeline with a larger one would require that the existing line be removed from
service for an extended period of time, during which Dominion would be unable
to supply the natural gas requirements of its customers. In addition, the larger
pipeline would require a larger construction right-of-way, result in greater
environmental impacts and significantly increase the difficulty of the construction
process, including such items as directional drills.
Q. What is the width of the construction easement
needed for the proposed pipeline expansion when paralleling the existing pipeline,
when using a route in an existing power line easement, and when using a totally
new route. What must be done to the land, ground cover, trees, etc., to permit
construction?
A. The typical width of construction right-of-way required will be 75 feet for
the proposed pipeline, whether we are paralleling the existing pipeline or not.
This land will be cleared of trees and vegetation. Paralleling the existing
pipeline minimizes the need for additional cleared area, since at least 50 feet
should already be clear. It is unclear to what extent the various power companies
would allow Dominion to use their easements on a temporary basis for construction,
but Dominion will not be able to locate the proposed line significantly within
an existing power line easement.
The entire length of the pipeline will have a 50-foot wide permanent right-of-way
– 25 feet on both sides of the centerline. Land agents are available to
discuss individual circumstances with landowners.
Q. Does the right of eminent domain, once gained,
extend to acquiring rights-of-ways and/or easements along those owned or used
by other utilities?
A. We are too early in our project to contemplate eminent domain and we are
pleased with our track record of successful negotiations over the years. If,
and when, condemnation becomes our last resort, we will evaluate the issues
at that time. Generally, public utilities and similar entities that provide
vital public services recognize the need to work together to provide these services,
so we do not expect that condemnation will be necessary in these cases.
Q. What specific issues are presented by running gas
pipelines under power lines of various sizes? If there are safety considerations,
whether construction or maintenance related or both, give the specific nature
of each and ways in which they are commonly minimized or obviated to permit
such combinations to exist. What industry standards and/or governmental regulations
apply, if any?
A. In general, power companies do not allow gas pipelines to be installed under
power lines. However, in certain cases, gas pipelines are allowed to share a
portion of the edge of the power company’s easement not under the lines.
Safety considerations when proposing a dual occupancy right-of-way (electric
and gas pipeline) are pipeline construction equipment working in and around
power poles; equipment coming too close to the power lines; damage to the power
company’s counterpoise; electrical shock on the pipeline during construction;
and remaining space for the power company to perform maintenance if necessary.
Q. On existing fence crossings, will a gate or gap be left
after construction to access and maintain the right-of-way?
A. Gates or gaps are the standard for access through fences on a pipeline right-of-way.
If the fence is a property boundary, both landowners must agree for the gate
or gap to be installed.
Q. After construction, will you access my property from
wherever you want, or will access be limited to the right-of-way?
A. Generally, Dominion will access the right-of-way from access roads and the
right-of-way where easements have been purchased. Dominion does not have unlimited
right to access to your property.
Q. What will be done to stop people from trespassing on
the right-of-way after construction?
A. Dominion will replace any fencing that is disturbed during construction.
In some cases, land agents are available to discuss specific concerns.
Q. What if I don't sign the easement?
A. This means that you and Dominion have failed to reach an agreement for access
to your property. Dominion has a good record of successfully negotiating easements
- that is, in a very high percentage of cases, we find a way to design an agreement
that works for both the company and the landowner. However, if an agreement
is not reached, after receiving Federal Energy Regulatory Commission approval
for the project, Dominion would have the right to use the court system to gain
access through eminent domain powers granted to it by the federal Natural Gas
Act.
Q. Once the pipeline is in the ground, how close can I
build a home?
A. Following construction, Dominion will have a 50-foot permanent easement -
25 feet on both sides of the centerline. A landowner can build up to, but not
on the easement.
Q. Can other utilities use this easement in the future?
A. Other utilities would need to negotiate a new easement with each landowner.
The easement agreement that Dominion will have with each landowner will be for
natural gas pipeline facilities only. Dominion cannot sublet the agreement to
other companies or utilities.
Q. Will I have to pay taxes on the money received for compensation?
A. It is best to consult your tax advisor.
Q. Will I have to keep paying property taxes on the right-of-way?
A. Yes. Dominion will not own the land for the pipeline. We will hold only an
easement for it. You still will have ownership and use of the right-of-way except
that you will not be able to build on it.
Q. When will I be paid for the easement?
A. Negotiations for the easement will include a detailed discussion on payments
for the easement. Typically, Dominion will obtain an easement option and make
a down payment on the full consideration. The balance of the consideration will
be paid prior to installation of the pipeline.
Q. Can I plant shrubs or trees on the right-of-way?
A. After construction, normal farming operations can resume. Landscaping can
be planted within the right-of-way in yard areas. However, if Dominion should
need access to the pipeline in these areas for maintenance work, these plants
will have to be removed. It is best to discuss your plans with your land agent
during easement negotiations.
Q. Can I build a driveway over the pipeline?
A. If you have specific plans to build a driveway over the area of the pipeline
right-of-way, you should show these to your land agent during negotiations for
the easement. If, some time after construction, you have plans for a driveway
installation, you must obtain prior approvals from Dominion.
Q. Can I cross the right-of-way with logging trucks and
heavy equipment?
A. Heavy equipment that crosses an unprotected pipeline can cause damage. Please
advise your land agent during negotiations if you will have heavy equipment
crossing the pipeline, and the pipeline can be constructed to accommodate this
use. See the answer to the question above.
Q. In general, what is the conventional excavation
process and what disturbance can be anticipated?
A. Generally, the surface disturbance due to pipeline construction is short-lived
and every effort is made to begin the revegetation process immediately after
final grading.
Q. What size area is needed to stage equipment for
crossing streams, creeks and wetlands, using both directional drilling and conventional
methods?
A. Many variables affect the amount of extra workspace required to stage equipment
for traditional stream, creek and wetland crossings. These variables include
crossing width, crossing depth and topography surrounding the wetland or waterbody.
Site surveys are required in order to minimize the impacts to the environment.
Dominion places extra workspaces and staging at least 50 feet from the edge
of wetlands or waterbodies except for special conditions.
Q. What techniques for grading would be necessary
for approaching streams, creeks and wetlands?
A. Dominion will follow the FERC’s "Wetland
and Waterbody Construction and Mitigation Procedures," as well as requirements
from the appropriate state, Critical Area Commission, U.S. Army Corps of Engineers,
and those of any other agency having regulatory jurisdiction.
Q. In general, what methods will be used to restore
disturbed areas to their original condition?
A. The land will be restored to its original contour following completion of
construction. The land will be replanted according to any of the following in
order:
land owner requirements;
special land-use requirements (critical areas, agricultural
lands, etc.);
county/state erosion and sediment control regulations;
and
Topsoil segregation and soil compaction mitigation shall be
performed in agricultural lands where required.
Q. What happens, both during construction and on a
permanent basis, to lands within 100 feet of streams, creeks, rivers and wetlands?
A. This varies on a case-by-case basis depending on land use, topography and
construction technique. It will be addressed in the FERC Resource Reports for
specific wetland and waterbody crossings once the documents are complete for
the proposed route.
Q. If directional drilling failed, what would be the
consequences?
A. Dominion is required to provide a contingency plan to the FERC in the case
of a failure of a horizontal directional drill. Although the details of the
plan are still being finalized, a conventional crossing would be the prime alternative.
Q. According to our maps, the distance across the
Patuxent River between Leitch Wharf and Chalk Point is not much greater than
the present pipeline crossing at Potts Point. What, if any, length limits apply
to directional drilling and what other factors would determine whether this
is a viable alternative?
A. The maximum length of a 36-inch horizontal directional drill is about 6,000
feet. This is highly dependent on soil conditions. The distance for a directional
drill from Leitch Wharf to Chalk Point would be a minimum of 7,000 feet assuming
the local electric utility would even allow us to perform such an operation
so close to their facility where they are bound to have significant underground
utilities and other structures. Moreover, the power lines on both sides of the
Patuxent River make sharp turns not far from the banks. This would mean that
many thousands of feet of virgin lands would have to be cleared in order to
lay out the drill string and achieve pullback. This is not the case near the
existing crossing of the Patuxent River where there is straight right-of-way
that can be used to lay down the horizontal directional drill string and the
crossing will be about 4,500 feet in length.
Q. If the pipeline trench splits my property, will I be
able to access the other side of my property during construction?
A. Arrangements can be made for you to have complete access to your property.
Discuss your access needs with your land agent.
Q. Will my water well or spring be impacted by construction?
Will you be responsible for any damages to my well or spring?
A. All wells within 150 feet of the construction will be tested both prior to
and following construction. Dominion is responsible for any damage to your well
that is caused by the pipeline construction.
Q. Will there be any blasting on my property?
A. Dominion will minimize the use of blasting to only those areas that require
it. If blasting is done, seismographs and a proven procedure followed by certified
blasters will be utilized to assure that vibrations from the blasting are kept
to a minimum in order to protect property.
Q. How close to a house or other structure can you place
the pipeline?
A. Generally speaking, the pipeline should not be closer than 25 feet to any
structure. There are certain instances where construction constraints may necessitate
the pipeline being closer than 25 feet to a structure, but these situations
are few and will be discussed on a case-by-case basis with individual landowners.
Q. What will be done with livestock during construction?
A. Where necessary, Dominion will construct temporary fencing and gates to contain
and protect livestock from the construction process. Dominion will make sure
landowners have access to livestock for feeding, watering, etc. Land agents
are available to discuss these concerns.
Q. What is the size of the pipe?
A. The size of the pipe will be dictated by market needs, which are still being
evaluated.
Q. How long will pipe segments be and how and where will
they be shaped?
A. An individual piece of pipe is called a "joint." Pipe joints for
this project will be ordered in either "double random" or "triple
random" lengths. The requirements for double random lengths are: the individual
joints are between 14 feet and 45 feet long with the average of the entire pipe
order being 35 feet per joint. The triple random length requirements are: the
individual joints are between 21 feet and 65 feet long with the average of the
entire order being 52.5 feet per joint. The pipe will be competitively bid,
but not until the year before construction. Only established, qualified bidders
will have the opportunity to present proposals. The pipe would be manufactured
at the pipe manufacturer's facility to meet the required codes and company specifications.
Q. Will pipe be thicker at bends or other locations? What
thickness if so?
A. No. Natural gas travels around bends without a need for thicker pipes. The
line pipe has limitations on how much it can be bent. For situations where the
bend is more than is allowed in the line pipe, manufactured bends are used.
These are called elbows.
Q. What is the construction schedule?
A. Construction on the Cove Point facility expansion will begin as soon as regulatory
approval is received. Construction is scheduled to begin in 2006, with the facilities
ready for service in 2008.
Q. How long will construction take?
A. Construction at the facility is expected to take about three years. Generally,
pipelines are constructed in a sequential process that includes the following
steps:
The clearing and grading crew leads the construction spread.
The trenching crew will use a wheel trencher or backhoe
to dig the pipe trench.
A stringing crew, using specialized trailers, will move
the pipe from the storage yard to the pipeline right-of-way.
The pipe-bending crew will use a bending machine to make
slight bends in the pipe to account for directional changes in the pipeline
route and to conform to the topography.
The pipe gang and a welding crew will be responsible for
welding, the process that joins the various sections of pipe together into
one continuous length.
Line pipe is externally coated to inhibit corrosion by
preventing moisture from coming into direct contact with the steel.
Lowering the welded pipe into the trench demands close
coordination and skilled operators.
Once the pipe has been placed in the trench, the trench
can be backfilled.
Before the pipeline is put into natural gas service, the
entire length of the pipeline is pressure tested using water.
The final step in the construction process is restoring
the land as closely as possible to its original condition.
Work will not occur on your property each day and there may be significant
lapses between certain activities. The construction schedule for each property
will vary depending on the size of the property, the amount of pipeline/easement
on the property, topography, weather and other conditions.
Q. How deep will the pipe be buried?
A. The pipeline will have a minimum of three feet of cover.
Q. What kind of steel is the pipe made of?
A. The steel used to manufacture pipe for the pipelines will meet or exceed
API - 5L specifications.
Q. How far apart are the mainline valves?
A. The mainline valves will be spaced according to the Federal Department of
Transportation (DOT) code. The spacing in the code is determined by the population
density. In the least populated areas, every point on the line must be within
10 miles of a valve; the second least densely populated areas within 7.5 miles
of a valve, the third least populated areas within 4 miles, and the most populated
areas within 2.5 miles. The actual spacing is being determined and will be included
in the FERC application.
Q. How much space does a mainline valve require?
A. Typically, a 50 foot by 50 foot square, with road access is required.
Q. What is the width of the easement for maintenance
of the proposed pipeline expansion in Maryland and what will be the condition
of the land along it, including ground cover, trees, etc.? Is this width the
same for the entire length of the pipeline?
A. The proposed pipeline expansion will generally run parallel to Dominion’s
existing TL-522 pipeline. Certain portions are proposed to pull away from the
existing pipeline. In the areas where the two pipelines will run parallel, Dominion’s
permanent easement for maintenance and operation of both lines will not exceed
75 feet following construction. In the pull-away areas, Dominion’s permanent
easement for maintenance and operation of a single line will not exceed 50 feet.
During construction in cultivated areas, the topsoil will be segregated from
the subsoil. Following construction, the construction area will be restored
to contour and the topsoil will be replaced over the disturbed area. The disturbed
area will be re-seeded, fertilized and mulched. Dominion will monitor the re-growth
on the right-of-way. In addition, at periodic intervals following the construction,
representatives from FERC will inspect the right-of-way to ensure satisfactory
restoration.
Q. Will you have the right to use my access road after
construction?
A. Easements for all access roads utilized for this project will be purchased
as permanent access roads and may be used from time to time by Dominion to check
the pipeline and perform routine maintenance operations and safety checks.
Q. How will the line be inspected once it's built?
A. The pipelines will be inspected and tested regularly to identify potential
problems.
During pipeline construction, all pipe welds are x-rayed to
verify that the welds meet the requirements of API-1104.
Then, before the pipe is actually placed in initial operation,
it undergoes hydrostatic testing. The pipeline is divided into different length
sections. The sections are filled with water and pressurized to levels well
above normal operating pressure, as required by Federal DOT code. Any pipe sections
with weaknesses are replaced or repaired before the pipe is put into service.
After construction, there is no routine hydrostatic testing of the pipeline.
Pipelines in operation are visually inspected by personnel
flying and walking the pipeline right-of-way. This visual inspection looks for
any natural or manmade conditions that could impact the pipe or affect its safe
operation. Factors such as excavation, construction work, soil erosion or landslides
could pose problems for a pipeline.
The effectiveness of the system-wide cathodic protection process
is tested routinely with "pipe-to-soil" inspections. Pipelines also
are regularly surveyed using sensitive devices called "sniffers" to
check for leaks. Sniffers are sophisticated electronic devices that can detect
even minute levels of natural gas in the air. Any leak detected is located and
repaired immediately.
Even though pipelines operate underground and out of sight,
they can be inspected from the inside using modern technology. Dominion uses
this "smart pigging" technology to measure and analyze conditions
along the pipeline's inner and outer walls. The "pig" device travels
through the pipelines and electronically reads and records the slightest change
in pipe wall thickness. These changes can pinpoint potential problems before
they become problems.
Q. Describe method and frequency of pigging and hydrostatic
pressure testing or other inspection strategies.
A. An internal inspection will be made right after construction is complete.
Information from this inspection will be used as a baseline to compare against
future inspections. Several factors are considered to determine the smart pigging
frequency. Future inspections would be made with a smart pig, probably every
seven to 10 years.
Q. What safety precautions will you take during construction?
A. Danger to the general public associated with natural gas pipeline construction
is minimal. No unauthorized personnel will be allowed into the construction
area. However, landowners who want to monitor the construction on their property
will be allowed access with the appropriate escort and safety equipment.
Q. What welding safety guidelines will be followed, i.e.
frequency of inspection, type of inspection, etc.?
A. Every weld on the pipeline will be non-destructively tested according to
API-1104. The currently accepted method is to use x-ray, but this method could
be replaced in the future by other non-destructive procedures that would meet
Federal DOT code.
Q. How does your leak detection system work?
A. The natural gas pipeline system is monitored 24 hours a day by Gas Control
Department personnel in Clarksburg, W.Va. They use computer-assisted control
centers that can detect and understand changes in pressures and flows. The company's
operational emphasis on safety includes compliance with the Code of Federal
Regulations, 49 CFR Part 192, and involves regular patrols of the facilities
by experienced observers in low-flying aircraft and routine ground patrols.
After construction, an internal inspection tool, known as a smart pig, will
be run on a regular basis, probably every seven to 10 years.
Q. How will a leak be handled once the pipelines are in
use?
A. The company follows a procedure that outlines repair methods for various
types of situations. The procedure is based on extensive research completed
in the natural gas industry. The type of repair will vary with the situation.
In most cases, the repair would likely involve removing the pipeline from service
and replacing the leaking pipe joint.
Q. How will a leak be identified and what is the maximum
expected time between a leak and the ability to shut off the gas flow?
A. Leaks can be identified by various means, including aerial patrol, foot patrol,
pressure monitoring, and third-party notifications. In most cases, the leak
can be isolated within a short period of time by remotely operating the mainline
shutoff valves.
Q. What is the volume of gas that could potentially be
leaked within that time frame?
A. The volume of gas escaping from a leak depends on the size of the hole, the
pressure in the pipeline, and the amount of time the leak occurs. Every leak
will have a different volume loss.
Q. Describe your disaster response plan. A. When Dominion gets a report of a gas emergency involving
our facilities, we
Identify the type of facility involved and the exact location.
We also gather information on injuries, if any.
Act immediately to notify emergency response agencies
and organizations in the area if necessary.
Isolate the affected facility and take all possible steps
to stop gas flow at the point of the leak.
Designate a single company person as contact for all outside
agencies and organizations.
When our personnel arrive at the
scene of the problem, we ask responding emergency units to
Establish perimeter control around the affected area.
Communicate and work with our designated company spokesman
in responding to the situation.
The following guidelines have been established:
Guidelines For Responding Emergency Units
When there is a fire:
Do not attempt to extinguish the fire unless life
is in danger.
Protect the area surrounding the fire.
When no fire is involved:
Remove any open flame or other possible sources of
ignition from the area and prohibit smoking.
Position apparatus at a safe distance and have all
personnel in protective clothing.
Control any secondary fires.
Assist with personal injuries and coordinate evacuation,
if it is necessary.
Assist Dominion personnel with access to valve locations
as needed.
Non-company emergency personnel should never attempt
to operate any valve connected to natural gas lines or facilities.
If it's appropriate, help with news media.
In any emergency, accurate communication and quick cooperation
between Dominion and fire or police units will be essential. When Dominion initially
communicates with any emergency response units, we will indicate the facilities
involved, the design and operating parameters, the nature of the product involved,
and the details of our response to the situation. Normally we will dispatch
personnel to the area immediately. We will also establish and maintain mobile
communications with the site until the emergency has been resolved.
Usually any emergency or potential emergency will be detected
and reported immediately through Dominion's ongoing monitoring of its facilities.
However, there may be situations when emergency units may report emergencies
where our facilities are directly or indirectly involved.
If you are reporting such an emergency to Dominion, please
provide all the data you can. Information about the facility, the nature of
the product, the location, and the observed condition of our facilities is needed.
Your information will be used to determine our initial response to the situation.
Generally the most effective way to respond to an emergency
involving our facilities is to shut off the flow of the gas. Please remember
that shutting off the flow is the responsibility of Dominion. Non-company personnel
should never attempt to use valves and controls. Dominion's personnel know the
piping systems involved and will make sure that correct actions are taken.
Q. What types of safety problems will be communicated to
the county and to whom?
A. Federal code requires notifications to DOT's Office of Pipeline Safety for
incidents and safety-related conditions. Required local contacts would be made
by the Company's Operations Department.
Q. How will you notify landowners, fire crews, and county
officials of problems?
A. Implementation of the Company's Emergency Plan will include a call to the
local 911 center (or first-responder fire department if there is no 911 service)
and/or law enforcement notifying them of the situation and requesting assistance,
if necessary. Company employees on the scene or local emergency personnel will
notify nearby residents, who will be evacuated if the situation warrants. Nonresident
landowners will be notified by phone or mail depending on the situation and
the availability of the landowner. County officials, such as the emergency response
coordinator, will be notified by company employees, either immediately or as
soon as possible. The first priority of the company is to protect human life.
Q. How do you train local fire departments and what type
of material/funding will you provide?
A. Initially, local fire departments will be invited to the closest compressor
station site for a tour. This will include a description of the properties of
natural gas and the equipment used. In addition to a tour, we will conduct a
"fire school," which allows the fire departments to experience a natural
gas fire. No special materials are provided. Funding, in addition to tax dollars
to the county, usually consists of an annual donation to the first-responder
fire departments. After the initial training, all emergency personnel will be
invited to an informational program every three years. Tours of facilities by
emergency response groups are always available. Please call to make arrangements
in advance.
Q. Will fail-safe relief valves be mechanical or computerized?
A. Relief valves vent gas from the pipeline, and are located only at compressor
stations. These valves are usually mechanical and are secondary safety devices.
Computer controls are the first line of overpressure control. There will be
valves that will vent gas from the pipeline, but they are called "blowoff"
valves. At the blowoff valves, there are also valves in the pipeline, called
"mainline" valves. These valves stop the flow of gas through the pipeline.
Some of the main line and blowoff valves are planned to be remote controlled
by company personnel, not computers.
Q. How is safety maintained at mainline valves?
A. Mainline valve sites are fenced with a 6- or 8-foot high cyclone-type fence
with gated entrance that is kept locked.
Q. Are the mainline valves automatic shut-off activated
by pressure loss?
A. No, the shutoff valves will be remote controlled with the ability to manually
close the valves at the location.
Q. What is the backup for computer or electrical failure
if computerized?
A. Electronic data will be gathered from the pipeline and sent to the Gas Control
Department in Clarksburg, W.Va. If there is a problem with the Gas Control center
or the building it is in, a complete backup center is located at another local
facility.
Q. What other safety features (i.e., double-wall pipe,
line volume and pressurization monitors) will be used?
A. The pipeline will not contain any double-wall piping. Volume flow on the
pipeline will be maintained through compressor stations that are set up to pump
specific volumes. Each compressor station is equipped with continuous pressure
control equipment and engine shutdowns to ensure that the pipeline's maximum
operating pressure is not exceeded.
Pipeline Benefits
Q. How will the pipeline benefit my community?
A. The pipeline will pay tax dollars to the local county and provide natural
gas infrastructure that is critical for economic development in many areas.
Q. Can I tap into this line to supply natural gas to my
home or business?
A. Dominion is an open-access pipeline, so anyone who can meet the criteria
could receive deliveries from the pipeline. Connections to the pipeline require
reimbursement for all costs to tap into the line and the construction of a measuring
and regulating station (M&R). The cost of a tap and M&R generally is
about $1 million. You also must contract with Dominion to ship the gas on its
pipeline system.
Q. Specifically how many creeks, streams and wetlands
have been identified on both current and preferred routes in Calvert County
in Maryland? Are there any known (on maps, topos or aerials) creeks, streams
and wetlands that you have yet to survey or on properties that have refused
to allow the survey process to take place?
A. This information is currently being developed and will be filed at the FERC
as part of the project application. It is expected that the application will
be filed in the first quarter of 2005. However, at this time, Dominion estimates
that somewhat over 400 streams and wetlands would be crossed for the 48-mile
pipeline loop in Maryland. Dominion believes that there are additional stream
and wetland crossings on the properties remaining to be surveyed, but until
the field surveys are carried out, we cannot report this data to FERC.
Q. Specifically, on which crossings of creeks, streams
or wetlands on the Dominion preferred route in Maryland will directional boring
be done?
A. Under Dominion’s currently proposed route, we plan to use a horizontal
directional drilling of the 36-inch pipeline beneath St. Leonard Creek, Hunting
Creek, Patuxent River, Jordan Swamp, Zekiah Swamp and Mattawoman Creek.
Q. About how many acres of land will have to be deforested
along Dominion’s preferred pipeline route?
A. Dominion is working to determine the number of acres of land that could potentially
be deforested along Dominion’s proposed pipeline. We do not have this
data at this time, but it will be completed and included in the Resource Reports
being sent to FERC.
Q. What environmental regulations cover the pipeline
construction process?
A. We work with federal, state and local agencies to design the pipeline route
to assure that the impact on the natural and human environment is minimized.
Among the federal programs or regulations that will be reviewed for any project
impact and any related compliance are:
Endangered Species Act of 1973
National Historic Preservation Act of 1966
Coastal Zone Management Act of 1972
Clean Water Act (including the National Pollutant Discharge
Elimination System program)
Clean Air Act
Archaeological and Historic Act of 1974
Wild and Scenic Rivers Act
National Wilderness Act
National Parks and Recreation Act of 1978
Magnuson-Stevens Fishery Conservation and Management Act
The project also will be reviewed for potential impacts under
state and local regulatory programs for environmental issues related to streams,
wetlands, threatened and endangered species, air, etc., including programs that
implement the federal programs listed above.
Q. Where will the water for hydrostatic testing come from?
A. Water for hydrostatic testing will come from streams and rivers along the
pipeline route. The actual water bodies to be used will be included in the FERC
application. Withdrawal of water will be made in accordance with all state permit
requirements.
Q. Where will the hydrostatic test water go when testing
is complete?
A. The water will be discharged back into a well-vegetated upland area, subject
to landowner approval, in a manner to avoid erosion.
Q. What is the process for hydrostatic testing?
A. Water is withdrawn from the predetermined water source through a screened
intake hose, per any applicable state permits. Once the pipe segment to be tested
is full of water, the pressure is pumped up to the required test pressure. The
test is held for the required time, usually eight hours. After the pressure
is relieved, the water is discharged through the erosion control structures
required in the permits.
Q. What will happen with welding contaminants in the water?
A. The water will be filtered and periodically tested during discharge, pursuant
to applicable permits.
Q. What solutions have you developed to problems that
exist along the present route in the Hunter’s Ridge area in Maryland?
What are the factors that will dictate final route choice in this area?
A. Dominion is not aware of specific problems in the Hunter’s Ridge area.
We acknowledge that this is an area that developed over the years and is fairly
congested, but our personnel have satisfactorily operated and maintained the
pipeline in this area. The development in this area may influence the final
route choice. A key factor is obtaining consent from the Southern Maryland Electric
Cooperative for the use of a portion of their easement for construction.
Q. What are the nature and locations of the specific
problem areas in the White Sands development along the existing route in Maryland?
For each, what solutions have been developed that allow Dominion to keep this
route as a viable alternative?
A. Generally, the extensive development of White Sands has made the placement
of a parallel pipeline very impractical from a construction and maintenance
perspective. Dominion has not been able to develop any viable alternatives that
place the line parallel to the existing line through the White Sands Subdivision.
Q. Assuming that a route around White Sands in Maryland
is selected, what are Dominion’s plans to remediate the existing problems?
Would these be part of the present project?
A. Dominion is not aware of any problems that need immediate remediation. The
issues at White Sands are more related to the difficulties that would result,
both during construction and during operation, that an additional line would
create.
Q. What specific additional routes in Maryland, other
than the existing and preferred, has Dominion thus far identified? What advantages
and disadvantages have been identified with each?
A. In our original scoping for the proposed line, Dominion considered alternate
routes that take the pipeline along existing power line corridors and across
property owned by the Calvert Cliffs Nuclear Power Plant. However, in response
to Concerned About Pipeline Expansion’s request, Dominion is evaluating
whether an easement across the Calvert Cliffs Nuclear Plant property is feasible.
Dominion believes there are many significant drawbacks to this route and expects
that in the end our proposed route will prove to be the most viable.
Q. How many homes or business structures are currently
within 100 feet of both the existing and preferred Dominion pipeline routes?
A. Dominion does not know the number of houses within 100 feet of either the
existing or proposed pipelines. We are, however, required by FERC to include
in the Resource Reports the number of houses within 50 feet of the pipeline.
Q. What type of pipeline was installed through White
Sands in Maryland?
A. The pipeline installed through White Sands in the 1970s is a steel pipeline
with welded joints.
Q. Is it externally coated to inhibit corrosion?
A. The Cove Point pipeline IS coated to inhibit corrosion. In addition, the
pipeline is operated with a cathodic protection system that also inhibits corrosion.
The cathodic protection system must be checked regularly by Dominion in accordance
with the Code of Federal Regulations (CFR) 49 Part 192. Compliance with this
Code is enforced by the Department of Transportation, Office of Pipeline Safety.
Q. How deep is it buried?
A. In general, the pipeline is buried a minimum of 36 inches deep to the top
of the pipe. However, in some areas it is buried deeper due to topography.
Q. Where are your mainline valves?
A. All pipelines are required by the Code of Federal Regulations (CFR) 49, Part
192 to have mainline valves installed at specified spacing along the line. For
security reasons, Dominion does not publicize the location of its mainline valves.
Q. What is the current condition of the pipeline?
A. In the summer of 2002, the entire length of TL-522 (87.7 miles) was inspected
using “smart pigs,” which perform internal inspections of the pipeline,
and was found to be in excellent condition, with no defects requiring remedial
work or pressure reductions in the areas where the proposed looping is to occur.
Since then, Dominion has performed routine tests of the cathodic protection
system on the line and there is no indication of any new concerns.
Q. What years was it inoperable, and why was it inoperable?
A. Dominion’s existing TL-522 pipeline has been in operation since it
was placed in service in the late 1970s. There was a period of several years
where the Cove Point facility was dormant, but during this time the pipeline
remained “in-service” with natural gas inside the line.
Q. Could it be seriously corroded now due to age and/or
disuse?
A. No. The smart pig tests performed in 2002 would disclose any serious corrosion,
and the continued monitoring of the cathodic protection system since then would
prevent any new corrosion.
Q. How is the line inspected, and how often? We do
not seem to have routine ground patrols and minimal air patrols?
A. Dominion’s TL-522 is patrolled via BOTH ground and air patrols. The
frequency of patrols is prescribed by CFR 49, Part 192. We are required to patrol
our pipeline in the White Sands area at least twice per calendar year, and at
an interval not to exceed 7½ months. We are required to inspect the road
crossings at least four times per calendar year, and at an interval not to exceed
4½ months. In addition, we are required to conduct leakage surveys on
the same frequency as the pipeline patrol (twice per year). Leakage surveys
are conducted in conjunction with patrols. However, Dominion exceeds these frequencies
in performing its patrols of the pipeline through the White Sands area. In addition
to regular patrols, Dominion personnel inspect the right-of-way as we perform
required cathodic protection inspections and Miss Utility investigations.
Q. Though the White Sands Civic Association protested,
why did the county allow the building of 12 homes on the pipeline right-of-way?
Was it because the pipeline had been abandoned?
A. Dominion cannot speak for the county’s regulations regarding setbacks
from established rights-of-way for building construction. In addition, the pipeline
has never been abandoned since it was originally placed in service in the late
1970s.
Q. Did the heavy equipment driven across the pipeline
during the building of these homes damage the pipeline? How would we know?
A. Heavy equipment has the potential to damage the pipeline, but fortunately
no damage actually occurred. We know this because in 2002 a “geometry
pig” was run through the pipeline, in addition to the corrosion smart
pig mentioned in a prior question. This geometry pig would disclose any deformations
in the diameter of the pipe that could have been caused by external forces such
as heavy equipment. None were found in the White Sands area.
Q. What about bushes, trees, fences, driveways and
so forth on the pipeline right-of-way? For instance:
A White Sands well is located within 7 feet of the pipeline.
One White Sands resident planted a tree directly on the
pipeline when told he could not.
Others have attempted to build sheds, and park vehicles
on the right-of-way.
People continually trespass on the right-of-way.
A. Dominion does not allow permanent structures, foundations
or deep rooted trees on its pipeline rights-of-way because these can impact
the pipeline and our ability to inspect, operate or maintain it. If these or
other encroachments are found during our routine patrols, they are handled on
a case-by-case basis. Dominion currently has a policy regarding encroachments
on its rights-of-way and if a landowner proposes any new construction, such
as a home, garage, driveway, etc., on or adjacent to the right-of-way, Dominion’s
field office in Leesburg, Va., should be contacted at (703) 327-4163.
With regards to the water well, it is not Dominion’s
preference to have such structures close to the pipeline, but this particular
well pre-dates Dominion’s ownership of the pipeline. We are aware of the
well and monitor it to make sure the situation with it remains consistent.
It is important to remember that Dominion does not own the
land, only an easement across it. Dominion cannot dictate land use to the individual
landowner unless it impairs the operation, maintenance or safety of the pipeline.
Permanent structures impact Dominion’s rights under the easement, but
parking on the right-of-way by the owner and most recreational usage by the
owner do not normally present a problem. Dominion will work with landowners
to prevent trespassing or other unauthorized activity on the right of way, via
such things as fences, gates, etc. Ultimately, the landowner must determine
what activities can or cannot be undertaken on his land, subject to Dominion’s
pipeline easements.
Q. Please give the names of those individuals in Calvert
County and Maryland state governments that are coordinating the flow of information
going to FERC with relation to this project?
A. Dominion is coordinating the flow of information to FERC.
Q. What regulations dictate how close a gas pipeline
can be to a nuclear power generating station?
A. We are in discussions with Calvert Cliffs regarding this issue and their
particular needs and requirements.
Q. What long-term plans (beyond 2008) does Dominion
have for further expansion of the Cove Point LNG gas facility that would require
even more pipeline capacity?
A. At this time, we do not know of a need for additional pipeline capacity beyond
2008.
Q. On an average, how many ships per month will it
take to support Dominion’s expanded production goals? If this traffic
is seasonal what is the monthly range?
A. This questions is difficult to answer because there are assumptions influenced
by many variables beyond Dominion’s control, including:
The demand for natural gas, both in the United States and
worldwide.
The future price behavior of natural gas, both domestically
and worldwide.
The availability of supplies of liquefied natural gas -
at economically competitive prices - overseas.
Geopolitical factors, including the stability of countries
in Latin America, North Africa and the Middle East exporting LNG.
Regulatory decisions by numerous federal and state agencies
governing the transportation of LNG.
The availability of adequate pipeline infrastructure to
carry the gas to market.
All of these factors preclude a reliable estimate of
the number of tanker trips per year to Cove Point. Dominion only provides terminal
storage and transmission services to its customers who own the gas and arrange
for the shipping and the frequency of ships. The storage capacity and send-out
capacity increases are based on Dominion’s long-term expectations that
LNG will play a greater role in meeting the nation’s energy needs, but
that it is impossible to predict the time period over which demand could possibly
rise to these levels.
