Linc Energy Blog

April is National Safe Digging Month. In fact this is the fifth year we’ve celebrated "call 811," and since 2007 there has been nearly a 31% drop in excavation accidents.

In “Natural gas leak detection and what to do,” I discussed methods of detecting, isolating and what to do in the event of a gas leak. I noted that the true first alert for detecting natural gas is the nose thanks to the smell, which raises the question – what is natural gas odorization?

Valve maintenance is critical to any damage prevention program as it ensures the proper functioning of a pipeline. After all, if your valves do not turn freely and seal properly, you have little or no control of your crude oil or natural gas pipeline. The following are tips provided by Mr. Ron Meade. Ron is the Sales & Marketing Manager of DUALCO, the manufacturer of grease guns, valve lubricants, sealants and valve maintenance training. He is also an instructor, a troubleshooter and considered a valve maintenance expert.

Complying with these suggestions ensure safety, make the pipeline workers’ jobs easier and more efficient thus reducing pipeline operating expenses.

Tip #1 – Create a system map
Create a system map showing the location of all your valves. Number the valves on the map, and then create a manual showing size, type, location description and applicable notes. Some companies already have this requirement, but verify what you have and add any unlisted valves. In the event of an emergency – it may save a life.

Tip #2 – Have the right fittings on hand
Different valve styles often require different lubrication fittings. For example a plug valve may require a Lube Stick Injection Fitting or “tall” giant buttonhead fitting. These are sometimes referred to as “lube screws” and have either an NPSM thread down or a coarse bolt thread down. They have either a single or a double built-in internal check valve.

Most gate valves and ball valves normally use the shorter, stubbier lubrication fittings with an NPT thread down. Giant Buttonhead fittings with either single or double check valves are used. Vent cap fittings with or without Giant Buttonheads are also used.

A good maintenance practice is to have available spare fittings of each type in your tool box.

Tip #3 – Lubricating the plug of older plug valves
The primary seal in older lubricated plug valves is metal-to-metal between the plug and valve body. As pressure is applied to the valve through the lubrication fitting it builds up in the lube sealant reservoir under the plug, eventually “lifting” the plug and forcing it away from the metal-to-metal seal. At this point the lube sealant moves up and around the plug, lubricating it and forming an internal seal between the plug and the valve body.

Tip #4 – Vent Cap lubrication fittings
Vent Cap type lubrication fittings come in a variety of configurations and sizes. Cap sizes vary from ¾”–16 UNF and 7/8”–14 UNF to the more common 1”–14 UNS. These fittings have a pair of vent holes in the caps which must be checked and cleared before removing them. This allows trapped pressure (if any) to vent before the cap is removed. For a short time, Grove had a solid cap fitting with flats cut on the fitting threads, allowing pressure to escape. In all cases the fitting is also known by the NPT male thread down. The most common are ¼”, 3/8”, ½”, and the occasional larger sizes.

Tip #5 Common safety breach – substandard hoses
The most common hand-operated valve lubrication gun is the 10,000 psi hydraulic gun with a 15,000 psi cushioned gauge, 10,000 psi working pressure hose (12” or 18”), a 10,000 psi machined gauge tee and a Giant Buttonhead Coupler.

Be aware of manufacturers or vendors outfitting lubrication guns with inferior hoses or cast tees with working pressures of 6500 PSI. While this may appear to be a great way to save money it’s a safety breach and potentially dangerous. If you are shopping for a grease gun ask the manufacturer the pressure class of these components.
To help determine if your unit has the wrong pressure hose, the units in question may have a short (11 or 12 inch) solid black hose with little or no information on it, and the tee may have a casting outside the United States. If you’re not sure of the pressure rating on your hose call the manufacturer or 877-5DUALCO, as substandard hose assemblies are dangerous though they can be easily corrected.

Tip #6 – Valve cleaners
Valve cleaners are manufactured to safely clean valves without damaging the valve or the seals. There are three basic types of valve cleaners:

Type 1 - Hydrating Agent
A common valve cleaner is an amber-colored hydrating agent and often consists of a vegetable oil, usually castor oil. It penetrates and softens materials such as old, hardened lubricants and sealants within the valve. The cleaner should be left in the valve between four and twelve hours or more to work effectively. Alternately, a channel can be forced in as little as 30 minutes but this is a temporary fix. These softened materials along with loose sand, rust and other trash can then be pushed from the valve by pumping in a good grade of fresh lube sealant.

Type 2 – Heavy-Duty Cleaner
Often a heavy-duty valve cleaner is needed. This type of valve cleaner is often used by operating companies because it will clean rust deposits, cut old heavy waxes, remove varnish, sand, dust, rust, old hardened lubricants and sealants and thoroughly clean valves. This cleanser should be used for at least four hours or more to do a thorough job. It must then be purged from the valve with fresh lube sealant.

Type 3 – Dispersing Valve Cleaner
A revolutionary new product which cleans the interior of the valve thoroughly, works in about the same amount of time as the others, is replaced by fresh lube sealant, and then disperses when it is pushed into the product stream is the dispersing valve cleaner. Dispersing valve cleaner as it is known has the advantage of not fouling such items as meters, orifice plates and so forth. If any of this material does reach them it can be cleaned with water instead of solvent.

Tip #7
To do their job properly, valve lubricants must function as valve sealants, and sealants must also function as lubricants. Because of their dual purposes we commonly refer to them as lube sealants. To determine the best lube sealant for your application you should consider the following:

1. What temperature range (high and low) will the material be subjected to?
2. What pressures will we be dealing with?
3. Is there any CO2 or H2S present? If so, in what concentrations?
4. Is there water present? If so, how much?
5. Are there any other contaminants which should cause concern?
6. Are there injected chemicals which control paraffin or other unwanted materials present?
7. Are there any problems that we are unaware of?
8. Do I want a lube sealant with a vegetable oil or a synthetic oil base?

Many castor oil based products have the advantages of synthetic oils; however they are less stable and subject to chemical reactions. Additionally, synthetic oil base has superior stability, longevity and is less expensive than vegetable oil based sealants. For these reasons we recommend using synthetic oil based lubricants.

"SAE AMS-G-6032 “Grease, Plug Valve, Gasoline and Oil Resistant” provides an excellent guide to valve lube sealant.

These tips are provided courtesy of DUALCO - the manufacturer of grease guns, valve lubricants, sealants and valve maintenance training.

In a down economy, manufacturers are becoming more creative by suggesting the reuse, recycle, repair or even exchange of their existing equipment rather than investing in new products. I’m seeing more and more manufacturers offering renovation or exchange programs such as DUALCO, the manufacturer of hydraulic grease guns for valve maintenance.

If you have a DUALCO hydraulic grease gun (models: 11035 and 11000R) that is in need of repair or service, rather than spending nearly $700 on new equipment consider having your existing grease gun refurbished or exchanged for a fraction of the cost. If your equipment is not corroded or abused and all its components are fully assembled, it is a prime candidate for this program.

For those owning competitive lubricant guns, DUALCO can rebuild or repair most hydraulic guns as the parts are usually interchangeable.

After the equipment is received by DUALCO it is inspected. While most hydraulic guns can be repaired, if DUALCO cannot rebuild or repair it, the customer is contacted to discuss options. As part of the program the units are: disassembled, major parts are re-plated (for model 11035), the rebuilt gun is assembled, new fluid is added, it’s inspected, tested and repacked. Included in the parts which are replaced are all “O” rings, leather cups, fluid bag/bleeder assembly, plunger and check valve ball, spring, washer and filter.

There are some components not included in this program. However they can be replaced if missing or damaged at an additional cost. Those components are: body, fulcrum assembly, grease barrel, grease barrel cap, fluid bag barrel or the fluid bag barrel cap.

DUALCO warrants the work up to 90 days. The cost of the rebuilding or exchange program is $289 which offers 60% savings over the cost of acquiring new equipment. Should a customer require exchanging the gauge and hose that cost is $199. If both programs are exercised (standard plus gauge and hose), the savings is 30% versus the cost of new equipment.

While these programs appear to be hardly a windfall, they show how manufacturers like DUALCO are stepping up and offering creative solutions when budgets are tight. To learn more about this program, email This e-mail address is being protected from spambots. You need JavaScript enabled to view it .
 

With the recent rash of natural gas pipeline explosions, many caused by pipeline corrosion, there is a watchful eye on how owners are handling the maintenance and repair of their pipelines. To some companies the problems may seem bigger than life as there are millions of miles of aging natural gas pipelines in the United States alone. Pipeline owners are being forced to take a proactive stance to this problem by identifying areas of their lines which are in need of repair, remediation or restoration.

A product called A+ Wrap manufactured by Pipe Wrap LLC has been identified as an effective method to extend the life of high pressure natural gas pipelines. The product has been tested, approved and meets D.O.T. requirements as a permanent pipeline repair. The repair solution is a strong composite sleeving system which permanently repairs gouges, cracks, dents as well as external defects associated with pipe that has been compromised as much as 80 %. The A+ Wrap system is composed of a two-part putty which is activated when mixed together, along with a composite wrap; it is pliable, water activated and restores pipe to its full-strength condition.

A+ Wrap repairs defects near welded areas (up to 50% wall loss) or along any shapes or configurations including reducers, bends, tees, manifolds or elbows. However, it does not repair cracks, gouges or dents in longitudinal or girth welds.

A+ Wrap requires no special tools for installation and can be installed on wet or dry surfaces or even submerged in water. The product however, can only be installed by trained personnel with factory or representative certification. The manufacturer also requires the installer be recertified annually. In Colorado and the Rocky Mountain States, Linc Energy Systems is a certified trainer.

As with other water-activated composite sleeving systems, A+ Wrap has a smart pig detect-ability element without the drawback of creating cathodic reactions.

Pipe Wrap's A+ Wrap has been identified as an effective alternative to sleeves, welding or complete pipe replacement. With the ever increasing amount of deteriorating pipeline in the United States, I’m sure we’ll hear more about the use of Pipe Wrap to repair or restore our aging pipelines.

For other helpful ideas on this issue, visit Effective corrosion prevention methods for pipelines. 

In a recent report by Fox News, a member of the Pipeline Safety Trust referred to our natural gas pipelines as a “ticking time bomb.” It would seem an alarming safety issue appears to threaten the mainland US. According to Fox News, the National Transportation Safety Board is holding hearings this week to gather supplementary information regarding the San Bruno natural gas explosion. Apparently, they’re seeking information that could help avert future accidents.

In the report, "Aging Natural Gas Pipelines Are Ticking Time Bombs, Say Watchdogs" it was noted:

• Fourteen people have been killed in gas pipeline explosions in six months
• Since 1990 there have been “2800 significant gas pipeline accidents”
• Over 900 incidents have led to significant injuries or death
• There are 210 natural gas pipeline systems
• 21,000 miles of lines running through populated areas

Rick Kessler of Pipeline Safety Trust says, "Cast iron pipe will fail and the law always envisioned that these things would be replaced over time. Well, here we are more than a century later and we still have these things in the ground… they are kind of a ticking time bomb."

By law, pipelines are required to conduct leak surveys which are one of the most effective ways to monitor pipeline integrity. Which pipelines are surveyed and when depends on many factors, like the age of the pipeline, its composition, the condition, the geography, the road, and of course population. Gas leak surveys are conducted by trained technicians using gas leak detection equipment.

With the Obama administration new regulations are on the horizon, which will increase the number of pipeline inspectors and provide more stringent leak detection measures. New regulations and proactive meetings can influence change to increase the safety of our gas lines. These are certainly moves in the right direction.

In the interim, as more incidents emerge, people are rightfully on edge. It is noted in the news report if you have questions or concerns about gas lines in your neighborhood call the pipeline. In an earlier entry, “Natural gas leak detection and what to do” I discuss what to do if you smell natural gas.

Photo Credit: http://www.msnbc.msn.com/id/39089768

Over the years I’ve been amused with the variety of responses I’ve received when I’ve asked, “What is cathodic protection?” If I’m talking to a corrosion engineer I get one answer, if I’m conversing with an operations person I get something different. I thought, ‘Here’s a challenge - let’s describe cathodic protection in a way a layperson would understand.’

Cathodic protection (CP) is a technique used to control the corrosion of a metal substance in various applications. Some common areas which apply this science are: fuel tanks, pier pilings, ships, offshore oil platforms and casings, metal reinforcement bars for concrete structures, as well as pipelines.

To simplify cathodic protection – assume you have a metal pipeline and you need to protect it against corrosion. Pipelines are generally supplemented with CP after being protected with an anticorrosion system (coating or wrap) as the primary form of corrosion protection. Otherwise the cathodic protection required to combat corrosion for an uncoated pipeline is excessive.

The first step in cathodic protection is to take the metal you are trying to protect (pipeline) and turn it into a cathode. A pipeline is normally anodic, it contains positively charged electrons. By supplying an electric current the pipeline becomes passive or cathodic. The science reveals that as long as the electron current is arriving at the cathode (pipeline) faster than oxygen is, then corrosion will be prevented or significantly slowed.

Pipelines commonly use Impressed Current Cathodic Protection (ICCP) which uses a rectifier along with anodes buried in the ground. The rectifier (a DC power source) supplies electrons to the system stopping corrosion of the pipeline and since the anodes don’t surrender many electrons they don’t corrode much either.

Sometimes it’s more economical to use a galvanic anode system in which the anodes (Magnesium, Zinc or Aluminum) are the electron source and are sacrificed and corrode over the steel pipeline.

The video below offers a simple representation of ICCP.  

I hope you enjoyed this back to basics session on “What is cathodic protection?”
 

Photo: http://140.194.76.129/publications/eng-manuals/em1110-1-4008/c-12.pdf

Pipeline corrosion and digging by third party individuals or contractors are among the two leading causes of pipeline accidents. In earlier posts, I’ve discussed the significance of protecting pipelines against corrosion. I also discussed the importance of calling 811 to locate the utility lines before digging. But calling 811 does not always guarantee your lines will be located, which made me wonder what makes pipelines and facilities locatable?

In Colorado, when calling 811 you will be arranging to have what is known as “Tier 1” utilities located. The 811 organization for Colorado is UNCC and they will additionally provide the excavator with contact information for Tier 2 utilities that are in your area, and it is the responsibility of the excavator or homeowner to call those Tier 2 utilities to request a locate.

After locators have arrived, sometimes the excavator or homeowner learns that their lines can’t be located. This usually raises frustrations and questions.

What makes a line locatable?

Most utility locating equipment uses a technology known as ground penetrating radar (GPR). Others may refer to it as electromagnetic pipe detection (EPD). This science is based on the principal that an electrical current will flow along a conductive material, creating a magnetic field which can be received as a signal, and indicate the presence of a pipeline by location equipment.

Most gas or oil transmission lines use carbon or low alloy-steels. These lines will generate a magnetic field when charged so that the lines can be detected. However, gas distribution lines are commonly polyethylene (PE) and will not carry a current. Therefore the line will not be locatable by itself, unless a tracer wire was installed at the time of pipeline installation.

In this case, tracer wire is installed next to a pipeline and made accessible at various access points like manholes, valve boxes, vaults, or other enclosed access devices. When the tracer wire is charged at an access point a magnetic field will provide a signal the locator can use with GPR /EPD equipment. Tracer wire makes non-locatable lines (made of polyethylene, plastic, fiberglass or concrete) locatable when they remain intact.

While tracer wire offers an effective way to trace a line, the system is not flawless. Some well-known reasons tracer wire fails are:

• The common material used in tracer wire is copper. Unfortunately, copper is expensive which has made tracer wire prone to theft and you can’t trace a line if it’s not there!
• Copper wire is inflexible and can break during installation and a broken line won’t carry the current.
• Many tracer wires have vinyl or nylon coatings which fail prematurely when the line is exposed to moisture.

Due to these common weaknesses, tracer wire manufacturers have been challenged to introduce alternatives.  Some product advancements include: corrosion resistance, superior strength and durability, and cost expensive alternatives to traditional copper tracer wire.

What makes utilities and pipelines locatable? Without a pipeline being constructed with conductive material or a line installed with tracer wire the line locator is left with line-of-sight locating which is highly subject to error.

The latest natural gas explosion in Philadelphia sounds the alarm for immediate action in improving the safety of natural gas pipelines. Tuesday night's explosion resulted in the death of one Philadelphia Gas Works employee and has left five others wounded including a local fireman. Eyewitnesses saw a 50 foot fireball erupting into the air over a northeast Philly neighborhood resulting in the evacuation of nearby residents and businesses.

• Enhance pipeline safety
• PG&E spiked 11 lines to legal limits since 2003

Why risk the lives of workers, or damage to the environment or incur litigation costs and penalties, when there are simple ways to promote damage prevention of your pipeline?

According to the Office of Pipeline Safety, the single greatest cause of accidents among natural gas distribution and transmission lines is digging by third party excavators.¹ The PHMSA’s (Pipeline and Hazardous Materials Safety Administration) website also suggests “a major cause of pipeline accidents is careless digging.”²

In June of this year, there were two back-to-back accidents in Cleburne and Darrouzett, Texas, where third party excavators damaged natural gas lines resulting in a rupture and explosion. Many were injured and three people died. In both accidents the pipelines were not clearly marked. At the Johnson County incident, there was only one permanent pipeline marker and it was about a quarter of a mile away, obscured by high vegetation. Enterprise Pipeline, the owner of the pipeline was found to be in violation of six pipeline safety rules and fined $120,000.³

The AGA (American Gas Association) states that the Natural Gas Industry spends in excess of six billion dollars each year in safety programs which include: 811 or “One-Call” program, marking pipelines, inspections and awareness. Yet, with all the programs and precautions taken, it comes down to one thing – pipeline safety begins with visibility. If you can see it – it’s more likely you won’t hit it and you’ll avoid an incident. 

Improve visibility of pipelines to promote damage prevention

Keeping visibility in mind, there are some simple and relatively inexpensive ways to promote damage prevention of pipelines by improving the visibility of the underground utilities:

• Pipeline Markers – the U.S. Department of Transportation requires that signs mark an approximate location of a pipeline. In general, they are placed at road, railroad and waterway crossings, except in urban areas where line locator services are available.  Rhino Marking and Protection Systems revolutionized the Damage Prevention industry when they introduced their TriView marking system in 1997.  The marker provides 360° visibility, is impact resistant, durable, weather resistant and green.  

•  "Call Before You Dig” or “One-Call” Program – 811 is a relatively new federally-mandated program developed to provide an excavator a way to have the utilities marked prior to excavation.

    

• Wrap Pipes for Visible Protection While Excavating – After calling 811 and the facilities have been marked, a contractor can carefully expose the pipeline and install a pipeline wrap which improves the visibility and protects the pipeline integrity during excavation. View the video below to demonstrate how Safety Wrap offers pipeline protection during excavation.

Damage prevention starts before digging

There is a proactive way companies can protect themselves from costly litigation and fines, like those penalties Enterprise Pipeline is currently facing. The CGA One-Call Systems and Damage Prevention Best Practices recommend that a contractor take and document the excavation site before digging. ⁴

“If locate markings are adequately documented through the use of photographs, video tape, or sketches before excavation work begins, it will be easier to resolve disputes if an underground facility is damaged due to improper marking, failure to mark, or markings that have been moved, removed, or covered. It is important for excavators and locators to document the location of markings before excavation work begins. The primary purpose of this best practice is to avoid unnecessary litigation and expensive legal fees for all parties involved.”
 

 By following this CGA Best Practice by marking ines before a hit, the excavator protects themselves against expensive litigation and penalties like Enterprise is currently facing. There are commercial “hit kits” which provide contractors marking posts and measurement tools needed to create photographic documentation which can be used to keep you out of court.

Perhaps we can learn from the recent tragic accidents in Texas. There are simple and relatively inexpensive ways to improve visibility of underground facilities and prevent accidents. We could better use programs like the “Call Before You Dig.” We should comply with DOT line marker regulations. We could enhance excavation methods by wrapping pipelines during excavating, and we could proactively document excavation sites before digging.

Picture above:  The Rhino HIT Kit is compliant with CGA Best Practices 5-11, where the contractor clearly documents markings and protect him or her from costly litigation.

 SafetyWrap video:

¹ Parfomak, P. CRS Report for Congress – Pipeline Safety and Secrurity: Federal Programs, 2008. Page 13.

² PHMSA. Retrieved on October 6, 2010, from (http://www.phmsa.dot.gov/portal/site/PHMSA/menuitem.ebdc7a8a7e39f2e55cf2031050248a0c/?vgnextoid=2c6924cc45ea4110VgnVCM1000009ed07898RCRD&vgnextchannel=f7280665b91ac010VgnVCM1000008049a8c0RCRD&vgnextfmt=print#QA_2
 

³ LUNA, T., September 1, 2010. Report: Human error caused June natural gas pipeline explosion that killed 1 in Johnson County. Retrieved October 6, 2010, from http://www.dallasnews.com/sharedcontent/dws/dn/latestnews/stories/090210dnmetexplosion.affe1b96.html
 

⁴ CGA Common Ground Alliance Best Practices Version 7.0. Retrieved October 6, 2010 from, http://www.commongroundalliance.com/Content/NavigationMenu/Best_Practices/Best_Practices_2010/BP_7.0_Final_March2010.pdf

Since the San Bruno explosion, the concern of nationwide pipeline corrosion has become a hot issue in the press. However, according to the Office of Pipeline Safety, the single greatest cause of accidents among natural gas distribution and transmission lines is digging by third party excavators ^(1).

In fact, the AGA (American Gas Association) sites that “nearly 60% of the incidents on utility distribution pipelines are due to excavation damage.” This certainly in indicative of the recent tragic excavation accidents in Texas this June where three people were killed and eleven injured.

In 1998, congress enacted a law establishing a national “Call Before You Dig” or “One-Call” safety program. It took years to bring the program to its current status, and in 2007 the CGA (Common Ground Alliance) launched the national “Call Before You Dig” program to increase public awareness of the one-call or 811 program for all underground facilities. The program allows all excavators and homeowners who may be digging, to call one number nationwide to arrange for marking or identifying underground utilities in an area that will be excavated.

How does the one-call or 811 program work?

The one-call program pertains to homeowners as well as contractors. Many homeowners discount their projects as not warranting an 811 call. How deep are you planning to dig? If you’re digging 12” or more you should call, but if in doubt always call.

Homeowners installing fences, mailboxes or decks, planting trees or bushes, building water features (ponds, waterfalls) or working with concrete should call 811. In fact, homeowners routinely fail to call and cause accidents which disrupt services of entire neighborhoods. There have been accidents which have resulted in injury or death. When failing to call and there is an accident, it is likely the homeowner (or contractor) will become the recipient of steep penalties and maybe even litigation.

To avoid the consequences of not complying, three days before any project which requires excavation, simply call 811. Your call will be routed to a utility notification center in your state. The 811 representative will notify all Tier I utility owners of the locate request. The representative will provide the excavator contact information for any Tier II utility owners, and it becomes the responsibility of the homeowner or excavator to call them.

Most locate crews will arrive in a few days and mark the underground utilities in the area you called about. Remember, once the lines are marked DO NOT DIG on top of any mark and be aware that a locate is considered by law to be good within 18” on either side of the locate mark. Also keep in mind that the locate marks are only good for up to 30 days (if they are still visible), and if you haven’t completed your digging by then you’ll have to call 811 again.

Keep in mind, you do not have to hire a private locate company to excavate. However, if you intend to engineer a project you should call a reliable private locate company.

You can find state specific information on 811 at http://www.call811.com/state-specific.aspx.
 

It’s simple – call 811 and utility locators mark the lines. 

⁽¹⁾ Office of Pipeline Safety (OPS). “Distribution Pipeline Incident Summary by Cause:
1/1/2006 - 12/31/2006.” November 13, 2007. [http://ops.dot.gov/stats/NGDIST06.HTM]
http://www.call811.com/about-us/default.aspx

 

In the wake of the San Bruno gas line explosion, two California senators filed legislation yesterday to increase the regulation of our nation’s pipelines.

Utility companies have been under pressure for years to increase their inspections and replacement of aging pipelines. The San Bruno explosion, resulting in seven fatalities (as of 9/22/10) and leveling nearly 40 homes (destroying over 50), has cranked up the heat even more.

In 2000, a gas pipeline exploded and killed 12 people near Carlsbad, New Mexico. In that explosion, the pipeline was also an aging one, dating back to 1950 and was investigated by the National Transportation Safety Board (NTSB). The cause of the rupture was determined to be from severe internal pipe corrosion.

Since the San Bruno explosion, reports have surfaced that aging pipelines are a threat to gas pipelines nationwide. The concern has been raised that more than 60% of this country’s transmission lines are over 40 years old and the life expectancy is around 50 years. The majority of these lines are made of steel which is prone to corrosion and many of the pipelines were installed before suburbs emerged, and now present the risk that they could leak or erupt … beneath now populated suburban neighborhoods.

In 2002, a law was passed by congress which required utilities to inspect pipelines that run through densely populated areas. While critics suggest that utility companies don’t want to spend money to inspect and repair aging pipelines, over 3000 problems were identified during the first five years of this legislation. This demonstrates that the regulation has identified and resolved precarious situations, but it also clearly reveals just how unstable our aging pipelines are.

Yesterday, Senator Dianne Feinstein and Senator Barbara Boxer introduced new legislation which would increase regulation of our nation’s pipelines.

“The pipeline explosion in San Bruno was a tragedy that must never occur again in any American neighborhood,” Senator Feinstein stresses in a statement. “That’s why today we are introducing legislation specifically designed to improve pipeline safety – and to establish penalties for violators.

“The American people must be assured that the pipelines that crisscross the nation and run beneath their streets are safe. This legislation is a strong first step in that direction.”

The Strengthening Pipeline Safety and Enforcement Act of 2010 expands on Ray LaHood U.S. Transportation Secretary’s legislation which was proposed last week, and would^(1):
 

• Double the number of federal pipeline inspectors (there are currently 100 inspectors each responsible for inspecting over 2,000 miles)
• Require the use of electronic shut off valves to cut off gas in an emergency rather than manual valves which need to be located and manually turned off
• Order the internal inspection of pipelines by robotic devices, “smart pigs,” or other methods which are deemed equally successful
• Prohibit pipelines from working at high pressure if the line cannot be inspected using effective assessment methods
• Priority will be given to aged pipelines in seismic areas

The legislation, being authored by the two California senators is calling for an increase in penalties for violators of the federal safety regulations. It’s unclear when this legislation will be put to a vote, though we are sure to hear more in the weeks to come.
 

 To the left, utility safety worker inspects pipeline and valve wrapped with Trenton Wax Tape for cathodic protection.

 ⁽¹⁾ California Senators call for tougher pipeline standards