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WHATCOM COUNTY COUNCIL
Natural Resources Committee
July 27, 1999
The meeting was called to order at 10:00 a.m. by Committee Chair Connie
Hoag in the Council Chambers, 311 Grand Avenue, Bellingham, Washington.
Also Present: Absent:
Kathy Sutter None
Tom Brown
DISCUSSION
1. PORTAGE BAY TOTAL MAXIMUM DAILY LOAD (TMDL) PRESENTATION
BY MICHAEL COCHRANE (AB99 -280)
Michael Cochrane, Northwest Indian College Biological Researcher, stated he
is running the Centennial Clean Water Act Grant through the Whatcom
Conservation District for doing fecal coliform monitoring for the Portage Bay and
Drayton Harbor Shellfish Protection districts. He would discuss the recent quarterly
results for the Portage Bay Shellfish Protection District monitoring. Results are
from April, May, and June. He compared the results to the first quarter results.
Both were compared to the Total Maximum Daily Load (TMDL) study the State
Department of Ecology (DOE) did in 1997 -1998. The TMDL study was a yearlong
study and was calculated on an annual average. These results are calculated on
seasonal quarterly results. The bottom line is that water quality in the second
quarter was worse than the TMDL and the first quarter of this year. Additions to
this quarterly study were to look at the North Fork and South Fork tributaries. They
collected data from River Farm. The Land Trust is taking samples on the North Fork
and South Fork twice a month for him. That data is included in the second quarter.
The geometric mean, which is the averaging method, has a standard for class A
water of 100, with no more than 10% exceeding 200. The geometric mean coming
out of the South Fork and North Fork is no more than three or four. It has an AA
rating. The geometric mean for AA is 50. It is well- within AA standards. Also, the
percentage of samples over 200 was broken out of the data. The Everson
geometric mean in the 2nd quarter was 19, compared to 9 in 1st quarter and 13 in
the TMDL study.
Hoag asked if they are comparing things within the same time frame when
comparing annual and quarterly results. Cochrane stated he was not. The TMDL
did sampling once per month; he was doing more frequent testing.
Hoag asked that future reports list the annual average that was under the
TMDL, and then what the results are of that comparable quarter, so they can get a
little better idea of the seasonal comparisons, since the information fluctuates by
season.
Cochrane continued to review the geometric means and testing data of the
different testing areas (handout on file). At the mouth of Kamm Creek, the
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Nooksack River backs up during moderate flows. It was a wet spring, so a lot of his
samples taken in that area were Nooksack River water. The results from upstream
at the second sampling station on Kamm Creek are more indicative of what is going
on in Kamm Creek.
Hoag asked for the sampling location where the counts were over 8,000.
Cochrane stated it was at Northwood Road.
Cochrane reviewed the results for Lynden and Scott Ditch.
Hoag asked if he tested above or below the sewer treatment plant in Lynden.
Cochrane stated they test above the sewer treatment plant.
Cochrane reviewed results from Fishtrap Creek. Fishtrap and Bertrand are
usually the highest loaders to the Nooksack River. Fishtrap 4 is the easterly
drainage that comes through town. It started contributing significantly between the
first and second quarters. Fishtrap 3, which is Double Ditch, stayed about the
same.
Hoag asked if that is the area through town where they had a sewage
overflow earlier, and whether they occurred before his testing dates. Cochrane
stated he didn't know the overflow dates.
Hoag asked where F1 is. Cochrane stated it is at the mouth, where it almost
joins the Nooksack River.
Cochrane reviewed the results for Bertrand, and stated B3 is the easterly
drainage to Bertrand. He then reviewed the results for Ten Mile. T4, which is off of
Ten Mile Road, had a significantly high count.
Brenner asked where T2 and T3 are. Cochrane stated T2 is on the Guide
Meridian and T3 is at Hannegan Road. He was still trying to figure out the effect of
Barrett Lake on T1. The Nooksack River also influences T1.
Brenner stated it is strange how high T4 is. Cochrane stated the DOE dairy
inspector stated there is quite a bit of animal access in this area. There is a little
activity farther up stream. It may well be the direct animal access.
Brenner questioned whether it is possible there are animals near his testing
sight, so the results would not be indicative of the watershed.
Sutter stated it would be more helpful if they knew the causes of
contamination.
Michael Knapp, Planning and Development Services Director, asked Cochrane
to go out with County inspectors to identify the testing sites so the County
inspectors could look for the sources. There have been a substantial number of
fines and correction notices issued, but nothing to identify specific locations.
Hoag stated she sent copies of the preliminary reports to Planning so they
could find out where this stuff is coming from and getting the problems resolved.
She requested Cochrane work with the Planning and Development Services
Department. Cochrane stated he would set something up with them.
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Nelson asked for information on how the sampling was done. Cochrane
stated he takes a grab sample. He takes a sterilized water bottle and dips it in the
first six inches of water. It is tested within 6 hours of collection at a DOE certified
lab at the college.
Chris Woodward, Shellfish Protection Districts' Facilitator, stated the Advisory
meeting was the next day and would be addressing dairy issues. State, County,
and Canadian dairy waste inspectors would be present to do more coordination.
Brown stated they need to separate the samples from both sides of the river
to isolate sources. Also, he had not seen any information on what Bellingham puts
into the bay from their sewer treatment plant. He asked if there was any
information. Cochrane stated the DOE's TMDL study sampled left and right bank.
He averaged those figures to get them more comparable to his work. It is difficult
to isolate left bank and right bank because they vary.
Brown stated the variation would indicate to him that there is a use on the
adjoining land that causes one to be hotter than the other. Cochrane staged the
results have not been consistent or much different.
Brown asked if anyone had taken the results and tried to identify the inland
land uses.
Steve Hood, DOE, stated the Bellingham wastewater treatment plant (WWTP)
received an award for three or four years for no violations on their permit. The
plant is not a big issue. They are allowed to discharge a geometric mean of 200
and no more than one sample per month to exceed 400. Their discharge would not
affect Portage Bay. He clarified that the TMDL was on the Lower Nooksack. DOE
does not have regulatory authority over Portage Bay or the mouth of the Nooksack.
Brenner asked if most WWTP have violations. Hood sated there are a lot of
parameters that have to be met. Having no violations in three years is significant.
Cochrane stated the bottom line is the station at Marietta results show what
is coming out of the mouth. That is what affects Portage Bay. There is a lot of
dairy waste management happening in the spring, when people are applying
nutrients to crops. In the next quarter, the counts should go back down as things
dry up and as dairy waste application reduces in activity.
Cochrane stated Portage Bay was a lot cleaner this quarter, even though the
Nooksack River was a lot dirtier. The Nooksack was going more towards
Bellingham than Portage Bay.
Cochrane moved on to review the results for Drayton Harbor. The first three
stations are not really important because they don't really have an impact on
Drayton Harbor. The Cain Creen and Cain Creek Outfall are about 4,000 feet away
from the entrance to the harbor. They don't have enough flow to push fecal
coliform into the entrance. He reviewed the results from Dakota Creek. In Dakota
Creek 4, which is the southern fork of Dakota Creek, had a high increase. D4 is at
Custer School Road, and drains an area with a fair amount of commercial dairy
activity.
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Cochrane reviewed the California Creek results. Both California and Dakota
creeks do not much exceed Class A water quality standards at the mouth. Both of
their flows result in a loading that doesn't really impact Drayton Harbor. The State
Department of Health (DOH) database show there is not a problem on the ebb tide,
only on the flood tide, which shows the creeks are not causing a problem on the
ebb tide as the water goes out. They only pick up the high counts on the flood tide.
Drayton Harbor would be approved if they only took ebb tide samples. The Port of
Bellingham and the DOH sampling has reported high counts at the Blaine Marina.
At the request of the Shellfish Protection District, he did a variability study one day
that looked at two sites at the Marina, which involved taking duplicate samples in
the water every hour. He found that near the road, counts were in 800's all day.
Past West Marine, counts were 20 and 30 all day on the ebb tide. This points to the
idea that there are isolated and discreet water bodies that are being impacted by
very local sources.
Knapp requested the code enforcement officers go along with Cochrane to
determine sources. Cochrane stated DOE is updating files and geographic locations
of dairy farms.
2. DISCUSSION WITH VARIOUS PIPELINE COMPANIES REGARDING
MONITORING POLICIES AND PROCEDURES (AB99 -281)
Hoag stated the committee understood they do not have jurisdiction over
pipelines in the County. However, there is a lot of concern about the safety of their
constituents. She wanted to know the existing rules and conditions, so if there is
an area that is lacking, the Council could lobby the appropriate jurisdictions.
Leigh Klein, ARCO Cherry Point Inspector, stated they are not one of the
primary pipeline operators on the County. They have three relatively short
pipelines they operate in the County. Their largest is 16 inches in diameter and
transports natural gas. It comes from the Canadian border at Sumas. It goes into
the ARCO refinery and continues on to Intalco Aluminum. The second line is a
crude oil transfer line, from the Cherry Point refinery to the Tosco Refinery and
connects into the TransMountain line. It is a five mile long transfer line. The third
line is a 6 -inch diameter liquefied butane line that runs from the Cherry Point
refinery to the Texaco terminal in Ferndale. It is also only five miles long.
Brenner asked if there is a TransMountain line that comes through the
Candadian border at Sumas. Klein stated TransMountain is a crude oil line and
brings it in from Canada. This one brings in natural gas.
Klein stated they inspect the entire pipeline rights -of -way every two weeks.
They do sniffing using instruments that detect evidence of hydrocarbon leaks. They
look at changes in ground contour, soil discoloration, grass height, dislocated
signage, softening of paving, and construction activity. They walk the entire lines
that are shorter. On the longer lines, they do a drive -by and drive along the rights -
of -way. There is an annual valve inspection and maintenance program to test all
the critical mainline valves. That applies to the natural gas line. The shorter, five -
mile, pipelines don't have intervening valves. They monitor the cathodic protection
system. He described the cathodic protection system, in which electric voltage is
applied to the pipeline to prevent external corrosion. It is a very well known and
understood process in the industry. There are two ways to prevent corrosion on a
buried pipeline. It could be coated to prevent external corrosion, and have a
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cathodic protection system. If, over time, a rock is pushed against the coating,
then there will be some flaws in the coating. Once the coating begins to break
down, the cathodic protection kicks in more and more. They operate synergistically
to prevent corrosion. All lines are coated and have cathodic protection the entire
length of all their lines. The rectifiers are inspected every two months to ensure
they are operating properly and putting out the proper voltage and current. At
least once per year, they measure soil potentials to check that the pipe is
protected. There are guidelines on what the potential needs to be to make sure the
pipeline is protected. They participate in the one -call system. If someone is going
to be digging, they call one number, and the one -call agency notifies all the pipeline
operators in the area of the construction. The system also includes telephone
cables and other cables, in addition to pipelines. They have Smart Pigged on both
five mile lines.
Hoag asked how often they run. Klein stated it depends on the situation.
They have done the crude line twice, once in 1994 and again in 1997. They are
scheduled to do it again the following week. They did the butane line for the first
time last year. A six -inch Smart Pig is new technology.
Hoag asked if they run the Smart Pig on a set schedule. Klein stated they
run them more frequently than typical. At the property in front of Intalco, there is
a stray current corrosion problem due to a high power usage. It can cause high
corrosion rates. They discovered this in the mid -90s. They did extra work to add
additional cathodic protection to that area in front of Intalco. They electrically
isolated that portion of the pipeline so it would be handled separately. Because of
the increased corrosion rates, they started running the Smart Pig more frequently.
They repaired the anomalies of the corroded areas to a certain depth. A new
cathodic protection system has been monitored for over a year, and has all the
proper standards at the proper range. They don't expect any ongoing corrosion,
but they will check, which is why they are going to two year intervals to check lines.
If they have solved the problem, then they will probably lengthen the Smart Pig
interval. Two years is very frequent. Intalco has also adjusted the way they
operate to reduce the corrosion rates.
Brenner questioned whether that would happen under high power lines.
Klein stated no. It sometimes occurs around railroad beds or other pipelines if they
have interfering cathodic protection systems. The Olympic pipeline also runs near
Intalco and is addressing the same problem jointly.
Brenner asked if they feel they have solved the problem. Klein stated he
believed they do. The only information they have so far is the cathodic protection
readings, which have all been good. Next week they will Smart Pig the crude line,
so they will have both the 1997 and 1999 results. They can locate the same spots
that were there previously, and would indicate whether there is an ongoing
corrosion rate.
Klein continued to state that they have a SCADA system on the natural gas
line, which is a control and data acquisition system. It continually monitors
pressures and flow rates. Longer, cross - country pipelines will have these sorts of
systems. They do any repairs in accordance with the American National Standards
Institute (ANSI) national standards, which are used throughout the world for design
and repair of pipelines, and also the State Department of Transportation (DOT)
regulations. The crude line, because it operates at a low pressure, doesn't fall
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under DOT regulations, however the two lines are right next to each other and are
handled the same, both complying with the DOT regulations.
Brown asked about the Smart Pig through the natural gas line. Klein stated
that line was built in 1990 and the coating is still good. They have not yet Smart
Pigged that line. The cathodic protection readings are still good.
(End of tape one, side A.)
Hoag asked if it is expensive to run the tests. Klein stated one hires a Smart
Pig operator to do the work. There are half a dozen companies in the world that
provide this service.
Brenner asked how long the coating lasts if it isn't disturbed. Klein stated it
doesn't wear away. The coating will break down locally in time due to wear.
Hoag asked Klein to go through her questions she prepared.
Pete Romero, ARCO, stated the natural gas pipeline has five mainline break
valves at five -mile intervals. If there was to be a rupture between one of those
intervals, it would automatically shut and isolate the system. They are
mechanically operated from a hydraulic differential pressure switch. Valves on both
sides of the break would close. The short lines have manual valves at the end of
each five -mile pipeline.
Klein stated they only find double walled pipes at roads crossings. The pipe
goes through a casing for extra support, but that has a number of problems
associated with it, including making the Smart Pig less accurate.
Romero stated they have casing on all pipes on all heavily traveled roads in
the County. Depth is monitored using an instrument to determine the depth. The
depth was engineered for 5 -6 feet deep. They will not inspect them except to
locate for digs. If they suspect there has been soil removed, then they will check
the line. They do an annual mailout for all property owners to notify them of the
location of the pipeline. Klein stated there is no leak detection on the crude oil or
butane line, other than pressure monitoring and monitoring the crude going in the
line and then coming out of the line. There is no actual system that indicates the
line is leaking. They do daily monitoring of the natural gas line. There is a
standard they balance the monitoring against, and they are usually under a 1%
variance. There are no ground movement sensors.
Bill Brausieck, Williams Northwest Pipeline District Manager, handed out the
DOT Pipeline Safety Regulations. It covers everything they will be talking about.
When they are talking about gas, they are talking about natural gas, as opposed to
gasoline. They are different products. Natural gas weighs less than air, which
means it rises above the air when released. From a leak detection standpoint,
there is no residue in the ground from a natural gas leak. It is a methane gas. In
its natural state, methane has no odor. The flammability limits are also
significantly lower than most other types of fuel except diesel. Williams owns and
operates five natural gas pipelines, and Northwest is one of them. There is a total
of 27,000 miles of lines within the Williams organization. The five companies carry
over 16% of the total volume used in the nation each year. Northwest pipeline
started out as Pacific Northwest and went through a series of owners. In 1997,
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Williams associated all their pipeline companies in a uniform direction, in terms of
economics and safety. Northwest Pipeline has 3,900 miles of pipeline. They
operate in seven western states. In Washington, they provide 95% of the natural
gas through local distribution companies such as Puget Sound Energy. Natural gas
transporter companies have changed in their focus of operation. In 1993, the
government mandated they no longer sell gas, only transport the gas. They
transport the gas at the request of the end user. They no longer own or have
custody of the gas. In Whatcom County, they get the natural gas at the border.
The pipeline runs south along the west coast of Washington. There is a 26 -inch line
installed in 1956, and in 1971 they added a 30 -inch loop line pipe. They operate at
800 and 960 pounds per square inch (psi) respectively. In Whatcom County, there
is a lateral run from the connection near Deming and Nugents Corner to the Britton
Road, where they have a metering station and transfer the custody of the gas to
Cascade. There was an original six -inch line. In 1992, they put in a 12 -inch line to
operate the co -gen at Georgia Pacific. The pipeline parallels Highway 9 down to
Seattle. At Sumas, there is compression to pull the gas along the pipe. One major
difference between gas and liquid pipelines is that gas is compressible. Liquids are
not compressible. In terms of regulations, they are regulated by the federal
regulations. On a rotating basis, they are audited by the Office of Pipeline Safety
(OPS), in addition to their internal pipeline safety department. Audits are very
rigorous and include several days on -site and several more days going over the
records.
Brown asked what they are looking for in the audit. Brausieck stated they
look at everything, including inspections, construction, and encroachments.
Hoag asked how often the audits are done. Brausieck stated it is done from
every one to every three years, depending on the availability of the auditors. They
do not get annual audits because the Office of Pipeline Safety has a good opinion of
Northwest Pipeline. They have received good audits in the past. Safety, reliability,
efficiency, and people are the four precepts that guide the company. Safety is a
performance measure for everyone in the company. Part of the employee
compensation is based on having a good safety record in terms of injuries and
violations. Regarding specific monitoring, cathodic protection and coating are the
two primary protections for the pipelines. All of their pipes are coated. The coating
is a low voltage DC current applied to the pipeline, and it travels through the
ground. Electrons flow from an anode to the pipe. Any place the coating is not
protected, the current goes to the pipe, which prevents metal from leaving the
pipe. When this is done right, the pipe looks brand new.
Brown asked if there is a life expectancy for a pipe. Brausieck stated if the
pipe is taken care of properly, there is a very long life expectancy.
Hoag asked about the coating on the lines in Whatcom County. Brausieck
stated the 1956 line is protected with a coal tar emulsion process. The 1971 pipe
has a thin film epoxy that was applied in the factory. If there is a hole in the
coating, a certain amount of current must go through to reverse the rusting
process.
Brown asked if one way to determine the condition of the pipeline is to keep
track of the currents being put out. Brausieck stated that was correct.
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Brausieck stated the one -call system is very important, and they do weekly
patrols via an airplane and an annual leak survey to check the entire pipeline.
Natural gas is not toxic, but displaces oxygen. Shallow cover, which is the depth of
the pipeline, is something they monitor for, but don't have a specific program for.
They've lowered the line in areas that may be susceptible to plowing. Public
education is important to let landowners know what the risks are if they plow.
Pipeline regulation depth depends on the circumstances, and can be from three feet
to twenty feet. Casing under roads exists for the old lines, not the new lines.
There is a problem with cathodic protection when the pipe is cased. Casing is
vented to the atmosphere. Where they can, they put heavier walled pipeline
instead of a casing. That is to protect the pipe.
Brenner asked about electronic leak detection. Brausieck stated they don't do
that. 3,900 miles of line makes that impractical. It is real easy to see if there is a
leak by the presence of dead vegetation and the odor. There is a natural byproduct
that comes from the wells where the gas is produced.
Brenner asked if natural gas would follow underground water into someone's
house. Brausieck stated, at a pressure of 900 psi, the gas would go up instead of
laterally into a water stream.
Hoag asked about sniffing. Brausieck stated they use a gas detector twice a
yea r.
Hoag asked about the shut off valves. Brausieck stated there are manual
valves at five to eight miles apart. They are in an industry where they supply
homes, hospitals, and industry. The leak detection valve technology is not a very
sophisticated science. They shut off accidentally. Trying to re -light a city is very
difficult and it is not worth the risk of accidentally turning off the gas.
Hoag asked how often the depth is monitored. Brausieck stated they have to
have a certain amount of depth to protect the pipeline. Whenever anyone calls with
an issue, they will inspect the area. In agricultural areas, they check for shallow
cover.
Hoag asked if those areas are walked at regular intervals with probes to find
out if they have shifted. Brausieck stated they do not.
Hoag asked if they have the hydrocarbon sensing cables. Brausieck stated
they do not.
Hoag asked if there are any ground movement sensors. Brausieck stated
there are not regular sensors. They have people annually looking at the areas.
They also encourage the public to call if they notice movement on the land where
the pipeline is. They have sensors on the hillside where the rupture occurred. They
spent $2 million and relocated that line out of an unstable area. They also put in a
monitoring system in that area to ensure there are not ongoing issues. They don't
have continuous sensors. They have sensors in areas where they suspect activity.
Hoag asked if the areas with monitors are continuously monitored. Brausieck
stated they are. They have to go out and take readings, but they are monitored
continuously. There are three types of monitors. There is the inclinometer, which
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monitors the shifting land. There are sensors right on the line that monitor the
stress on the pipeline.
Hoag asked about the monitoring that is occurring at the site that had the
landslide and explosion. Brausieck stated there are stress sensors, inclinometers,
survey points, and water level. The water level is the cause for the slides. Clear
cutting impacts the pipelines. The soil becomes over - saturated and causes the
slides.
Brenner questioned whether they notify new landowners. Brausieck stated
every year or two they do a land search of records. They also do annual mailings
to people.
Hoag asked how the monitoring information is collected. Brausieck stated it
is collected manually at different times of the year. It is done on a weekly basis in
very wet weather, monthly in the less wet weather, and every couple of months
during the summer.
Hoag asked if the two lines are side -by -side. Brausieck stated they are in
the same right -of -way with about a 24 -inch width between them.
Will O'dell, Cascade Natural Gas Director of Distribution Engineering, stated
that Cascade Natural Gas (CNG) serves 33,000 customers in Whatcom County.
They have 700 miles of main and 500 miles of service line. They are a distribution
company. They receive their gas from transmission companies. They odorize the
gas, and then distribute it to users.
Brown asked about the size of pipelines. O'dell stated the largest is 20
inches, and the smallest is a 5/8 -inch line, which is the typical service line going
into a home.
(Clerk's Note: End of tape one, side 8.)
O'dell stated he deals with natural gas. Natural gas in its normal state is
colorless and odorless. They inject an odor in that gas when they receive it from
the transportation company. The codes they operate under are the same as the
transmission lines. Since they are a distribution company in the State, they are
also regulated under the Washington Administrative Code (WAC) code 480 -093,
enforced by Washington Utility Commission, who oversees their operation and
inspects their facility and procedures. Key aspects to insure safety and system
integrity include a 24 -hour monitoring system, based out of a dispatch center in
Seattle. They can dispatch people to anywhere at any time.
Brenner asked about the pressure in their pipes. O'dell stated they have a
range of pressures. Normal lines operate at an intermediate pressure of 60 psi or
lower. Main feeder lines operate at 200 -400 psi. They do have some transmission
lines that operate at higher pressures. Of the 1,200 miles of line, only about 102
miles of lines operate above 60 psi. As they drop the pressure down, they have
regulator stations that can handle any abnormal operation. They have emergency
over - pressure protection, which goes to the meter set at the home. Any
abnormality will prevent pressure buildup at the home. They leak- survey the lines.
Depending on the pressure, they will be surveyed either twice a year to once every
five years for very rural lines. A leak survey is when someone walks the line with a
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leak detector. They also perform quarterly patrols. They visually inspect all lines
attached to areas that should be checked more closely. Most new lines are made
out of polyethylene. They also have the same cathodic protection and coating
requirements.
Brown asked if they are also installing a locating wire with the polyethylene
lines. O'dell stated they are. They are installing a tracer wire. There is public
education with fire departments and schools. They also are actively participating in
the one -call centers. There is a maintenance program for valves and regulator
stations. They also use markers similar to the ones Northwest Pipeline uses to
locate the proximity of their lines as they cross roadways and fence lines. Markers
within the town don't last very long. During the survey, they replace the markers
that have been removed or mowed over.
Brown asked about restrictions on activities above the lines. O'dell stated
that no building activity is allowed. They do allow paving or a garden and uses,
which only affect the upper surface level. They don't allow anything that could
affect the subsurface.
Brenner asked about tree roots. O'dell stated there is no prohibition.
Brenner asked if they ever disturb the lines. Will stated they mostly do not.
O'dell stated all valves are manual and are located on the main lines. With a
polyethylene pipe, they can squeeze the pipe off specifically where they want it, so
they do not need to find a valve to isolate a section of pipe. They go right to where
they want to shut down the pipe, and crush it down. Crushing the pipe will result in
a 100% shut -off. They do have the cathodic protection against corrosion. The only
time they install casing is when required by jurisdiction. They firmly believe it is
detrimental to pipes. It is a point of failure because they can't do cathodic
protection on pipes that are cased.
Brown asked if a casing material of a material other than metal would inhibit
the cathodic protection. O'dell stated it would still create the shielding. The pipe
needs to be in contact with the soil.
Sutter asked if the polyethylene pipes are going to be double - walled or
cased. O'dell stated they are made of a plastic, so corrosion is not an issue. The
polyethylene pipe they install is, at the largest, four inches in diameter. Anything
larger than that is a steel pipe.
O'dell stated they do not monitor the 1,200 miles of pipe for depth. They
have sensors that can accurately determine the depth if they need to. They have
no leak detection systems in place. There are no hydrocarbon sensing cables or
ground- moving sensors. Their smaller diameter lines are more capable of handling
ground movement than larger diameter lines. Regarding the spacing of the block
valves, on the larger lines, they design to a class 4 location, which is the equivalent
of a four -story building. It is the most rigorous design standard, and all lines are
designed to a class 4 location, which requires a block valve every five miles.
Hoag asked about Williams' leak detection and if they measure what is going
in and out of the line. Brausieck stated the leak detection measures what goes in
and out. At their pressures, any significant leak will be very obvious to the public,
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who is the main source of leak detection. There is also a sophisticated SCADA
system that monitors the pressure.
Brenner asked about the smell of methane gas. Brausieck stated that it does
not smell.
Brown asked about the Williams pumping stations and whether they are
monitoring what is happening between each station. Brausieck stated they are.
The biggest issue is the rate of change of pressure.
Hoag questioned how they addressed the problem of not being able to get to
the manual shut -off valve during an emergency. Brausieck stated they are working
with all emergency services to establish links. The Sheriff has promised escorts.
Generally speaking, they are not currently set up for remote operation with the
number of mainline valves they have.
Brenner questioned whether they could install remote shut off at certain
distances. Brausieck stated they do have them at about every 40 miles between
compression stations. Once there is shut off, it takes a half hour to 45 minutes for
the pressure to reduce to zero.
Hoag stated that, if the distance between the shut -off valves was reduced,
the length of time to reduce pressure to zero would be reduced also. Brausieck
agreed.
Hoag asked if they run into stray current problems in other locations besides
Intalco, such as substations. Brausieck stated high - voltage lines have some
impact, but it is mitigated.
Klein stated they don't have any substations.
Hoag stated she is aware of a gravel pit that has five of these lines in the
area. She questioned whether electrical machinery that is operated by the gravel
pit, such as a big generator used to run a rock crusher, would pose any problems
for stray current. Brausieck stated it wouldn't.
Hoag asked about the gravel trucks going across the lines as they leave the
pit. Brausieck stated it is a function of depth. When they bury the line deep
enough, it is protected and cushioned by the earth above it.
Brown asked about the pipeline work going on in the County. Brausieck
stated they are in the process of replacing the mainline valves so a Smart Pig could
be run through the line.
Brown asked how much it costs to Smart Pig a 40 -mile stretch of line.
Brausieck stated it costs about $200,000 to $300,000 for the work itself, not
including the evaluation.
Klein stated they are paying $80,000 to run the Smart Pig through five miles
of their pipeline next week.
Brown asked who evaluates the Smart Pig information. Brausieck stated
both they and the Smart Pig operators evaluate the information. As the expertise
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builds up in- house, they learn how to interpret the results. This is a non - regulatory
requirement and is not mandated in the industry. They have to be able to build
new facilities to run the Smart Pig.
Brenner asked how many gallons of natural gas is 1% if they are running at
full capacity. Klein stated they don't measure natural gas in gallons. He would find
out that information.
Brausieck stated they measure in standard cubic feet. The measurement
depends on what is going in and what is going out.
Klein stated the 1% measurement doesn't mean they are losing gas, it
means the accuracy of the readings have to be within the 1 %.
Hoag requested that the companies answer the rest of her questions and
mail them back to her.
Brausieck asked for clarification on Hoag's question regarding replacement of
a pipe. Hoag stated her question was focused on any problems that may be found
during an inspection.
Brenner stated the County Council, as the Health Board, has jurisdiction over
accidents that affect County residents.
ADJOURN
The meeting adjourned at 11:55 a.m.
Jill Nixon, Minutes Transcription
ATTEST:
Dana Brown - Davis, Council Clerk
WHATCOM COUNTY COUNCIL
WHATCOM COUNTY, WASHINGTON
Connie Hoag, Committee Chair
Natural Resources Committee, 7/27/99, Page 12