May 17, 2012

NERC Compliance Could be Tougher in 2011

James Holler, Founder, Abidance Consulting

As one year winds down, let’s peer ahead to see what compliance “surprises” could come from our friends at NERC in 2011 and beyond.

We all know there are no guarantees that there won’t be any “surprises” next year or beyond. What we, as an industry, do know is that there is going to be a new version of the CIP requirements that will cause most, if not all, registered entities to become a low, medium or high impact critical asset. This change will require registered entities to prepare new policies and procedures as well as implement a series of fail-safes to protect the facility from a physical and/or logical intrusion.

Beyond the revised CIP requirements on tap, there is no telling what the compliance future holds in store for us. This past year there have been multiple NERC Alerts issued that would have affected a majority of the registered entities to some extent.

Then there was AURORA, a big NERC Alert that did affect the current status of many registered entities. As you may know, this alert was issued in October and gave registered entities only a few weeks to respond to NERC.

Next year may have a similar number of Alerts issued, there is no way to determine what may or may not affect you until the Alerts or directives are issued either by your region, NERC or even FERC. One way to stave off any unforeseen expenses, including some of the ones registered entities incurred this year, is to outsource all of your NERC compliance efforts for a fixed fee via a Master Services Agreement (MSA) to either an internal corporate division or to a competent consulting firm. In either case, whomever you outsource your compliance efforts to must be fully adept at both CIP and Reliability Standards. This outsourcing could, in effect, negate any unforeseen expenses for consulting and other initiatives since all NERC Alerts, etc. would be covered.

In addition to helping you prepare for and handle a prospective audit, your consultants should also be responsible for keeping you compliant at all times, filing the appropriate self certifications, self reports, updating all policies and procedures to reflect any changes that may occur and also to address all NERC Alerts and new requirements that affect you.

James Holler is founder of Abidance Consulting.

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Beware the NERC CIP Consultant Spreading Rumors

James Holler, Founder, Abidance Consulting

I’ve noticed a new and troubling trend recently: There are a few consultants and firms using scare tactics to scare potential clients into becoming paying customers. Many of these consultants use misinformation and half-truths to spread their fear mongering on social network sites such as LinkedIn. Unless FERC, NERC or one or more of the eight Regional Entities has been directly quoted, naming the source, or if you can’t confirm comments or statements by a consultant, it is recommended that you contact these organizations for confirmation.

A good example of this is that there is a consulting firm spreading wild rumors and accusations around that there is going to be a CIP version 5, with set of rules that is radically different than what is in place now. Well, having spoken to Commissioner Spitzer’s office at FERC, there are no immediate plans for a version 5 of the CIP requirements. Version 4 has not even been approved by FERC, therefore, FERC can’t even contemplate when or even if there will be a version 5 of the CIP requirements.

Some members of the Standards and Development Team that is working with NERC to create the various CIP rules and changes is made up of a team of industry experts – some more knowledgeable than others – that create the modifications or new requirements. These are then put out for vote by the industry. If they are approved, then the CIP requirements are presented to FERC for their approval. More times than not, FERC will refer the presented rules back to NERC for modification or makes requests for clarity and guidance. The Standards and Development Team is not the defacto word in the CIP requirements, FERC is.

To sum up, don’t believe everything you read or hear. I do recommend that you get independent verification from FERC, NERC or your Regional Entity. If the consultant is using scare tactics to get you to sign a contract, they are only interested in making a quick dollar and do not have your best interests in mind. There are literally hundreds of people on the Standards and Development Team, so if someone touts that they are on the team, that’s nice…so are many others and they aren’t going around using scare tactics to get you to sign on the dotted line. My best advice is to do your due diligence before you jump simply because someone told you the sky is falling.

James Holler is founder of Abidance Consulting.

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Are The NERC Requirements Strong Enough To Protect The Power Grid?

James Holler, Founder, Abidance Consulting

The NERC requirements might help the people at NERC and the regions get a better night’s sleep, but a sound action plan, including situational awareness, is the only true way to get there — and ensure greater cybersecurity for all.

With so much at stake, NERC is faced with a daunting challenge of locking down the nation’s cyber infrastructure as it pertains to the power grid. NERC has forced registered entities to establish programs for securing their Critical Assets and Critical Cyber Assets that includes dedicated management, oversight, accountability of corporate officers, processes for securing IT systems, and mechanisms for measuring progress.

Of course, just meeting NERC requirements doesn’t mean a registered entity is secure. NERC should recognize its shortcomings and pass a measure that will, among other things, strengthen the role of an industry recognized leader like the National Institute of Standards and Technology in shaping cybersecurity requirements.

So, why is cybersecurity such a challenge? That’s a loaded question because today’s information infrastructure is a quandary. Some of the issues are:

Advanced Persistent Threat

Cyber criminals have become more sophisticated, outpacing defensive measures. Hackers constantly exploit weaknesses in popular products and create new techniques using viruses, rogue antivirus software, keystroke loggers, botnets, and other tools, for immediate targets or time-triggered actions.

New Dynamics

Registered entities have completely changed the way they communicate, interact and accomplish their missions. They’re sharing information in new, amazing and sometimes scary ways—from portals (regional scale for the most part) to social networking websites like LinkedIn. They’re even bringing trusted third parties into the fold. And their flexible IT model is establishing technology options that could present more risks, such as mobility and cloud computing.

Shared Risk

All of this is extending NERC’s reach into the critical infrastructure. Yet, 95% of that infrastructure is in the hands of the private sector. Risk to that infrastructure, information assets and private data is rampant with potentially deep and catastrophic consequences. The fact is, registered entities are giving more and more access to data and applications, a concept that runs counter to most security type of thinking. Traditional network security that relies on reactive measures simply isn’t enough.

Pay Closer Attention To Applications

Whether off-the-shelf or home-grown, most applications are not engineered with security in mind, so you need to ensure trusted development processes to maintain their integrity. Today, that means adhering to requirements set-forth by the NERC requirements. Trusted delivery is also critical — especially with innovations like cloud computing. Protecting the perimeter around applications is not a sufficient defense and you must extend security to the application layer. In every case, you need to be able to measure an application’s ability to process and handle sensitive information throughout its deployment lifecycle.

James Holler is founder of Abidance Consulting.

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NERC Requires Aurora Compliance by All Registered Entities

James Holler, Founder, Abidance Consulting

If you run SCADA/EMS data exchange networks and are located 1 substation away from a generation plant then the Aurora vulnerability should be on your mind considering the latest NERC Alert. The CIP Standards will not help you out of this vulnerability; neither will “normal” protection schemes. Idaho National Laboratory (INL) blew past those in seconds with time to spare, just like a well trained adversary will (see video below). Since that time, there are many small and midsized entities that are vulnerable as vectors to allow an adversary the ability to reproduce this catastrophic physical failure on a grand scale.

The vulnerability in a nutshell is that by physical or cyber means an adversary gains access to the breakers up to three substations out from a generator and ‘bangs’ it out of phase. By how much out of phase is still something of a mystery to many who are not protection systems engineers or generator folks. Suffice it so say that they are very aware of the worst case scenario of phase alignment problems. Aurora creates this in a split second. One second your generator is humming happily and then next it has broken couplings and a mangled shaft. It leaves you scratching your head and putting out fires.

There is hope and now a reason to get this problem fixed. The first step in doing this is to create an inventory, the second is getting your best protection people, cyber folks and substation folks together to see what ingress point you have to your substations. Next is cutting off the “pipe”. If you are running modem access to your RTU’s you need to stop it. This is not good business practice unless you have encryption and password protection. Also of note are the engineering access points. If you have the access points set up on a VPN, you might have allowed split tunneling which is not a good idea. Last but not least is that entities need to start talking amongst themselves.

If you are a registered entity then you should be talking to whoever owns the next substation out from your onsite substation to see what they are doing to protect your assets. This affects most registered entities to some extent.

In order to comply with the NERC requirement you will have to create a mitigation plan and continue reporting to NERC every 6 months until you have mitigated this issue.

A complimentary Webinar “NERC AURORA Compliance: Are you Ready?” will take place on November 11, 2010. You can register here.

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NERC Adds Heavier Fines, CIP Violations to Latest Enforcement Actions

Michael Causey, Editor & Publisher, eDataIntegrityReport.com

NERC is mad as hell, and they’re not going to take it anymore.

Okay, maybe that’s stretching it a bit, but take a look at their latest batch of tougher enforcement actions that hit some regulated entities with some heavy penalties.

Former cyber security specialist in FERC’s Office of Electric Reliability Randal Blanchette believes the upswing can be partially attributed to the simple fact that more and more entities are being audited for CIP-002 through CIP-009 generally.  “There are also more complexities [for companies to comply with] as newer revisions come out,” he adds. We’ve talked to Randal before about confusing NERC  regulations.

But Abidance Consulting’s James Holler says NERC is “flexing its muscle a bit.” They’ve been “nice” to regulated entities up until now, “but now they are saying it’s over.”

He noted a lot of six figure fines among this recent slew of penalties. “Those who didn’t take NERC seriously better start doing so now.” NERC observers tell us that in the past, few NERC citations carried a price tag for regulated entities. “We gave you a break and you took advantage of it,” is Holler’s view of NERC’s new attitude. “Some of you were slow to get your compliance programs in order and NERC wants to show they mean business now.”

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How to Interpret a NERC Requirement

James Holler, Founder, Abidance Consulting

As many of you know, neither FERC, NERC or your Regional Entity (FRCC, MRO, NPCC, RFC, SERC, SPP, TRE, WECC) has been willing to give any kind of interpretation for many of the NERC requirements. For example, if you want to know what the definition of annual is, neither NERC nor any of the regional entities will give you a “hard answer”.

With that said, here is a piece of information you may want to hold onto. If a requirement has not been officially interpreted in writing by the regional entity or NERC or by a FERC Order, Ruling or case decision, then the registered entity can choose its own interpretation as it applies to best business and utility practices for their environment. This interpretation should stand up in court and it is, for a lack of better words, FERC’s Achilles Heel. The registered entity interpretation must be in writing and widely disseminated throughout the organization if the registered entity expects their interpretation to hold up.

Here is an example of an interpretation – feel free to use the one we are providing – that you could use for CIP-008, R1.1:

Procedures to characterize and classify events as reportable Cyber Security Incidents

The response plan must allow for characterizing a reportable Cyber Security Incident by determining if the incident is/was malicious or not, equipment/property was stolen and/or destroyed, length of the incident (if cyber, how long the attack, etc., went on for), are you able to recover from the incident or not – if you can recover, how long will it take.

The response plan must allow for you to classify the reportable Cyber Security Incident by determining if the incident was a reoccurring incident, one-time event or a peripherally related attack, etc. Was the incident detrimental or not to the operations. Was the incident preventable?

As a registered entity, please be reminded that you need to use common business sense and good utility practice when creating/presenting your interpretation(s). Do not interpret a requirement as being something that it clearly is not. In other words, don’t interpret sabotage in CIP-001 as being only an event that is caused by a terrorist. A perfectly acceptable method is to look up the definition of sabotage in the dictionary and use that definition as a guide or starting point.

The information given in this document was garnered through conversations and Q&A sessions with various members of FERC, NERC and several regional entities.

James Holler is founder of Abidance Consulting.

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NERC/FERC Compliance Standards Too Vague, Former Official Says

Michael Causey, Editor & Publisher, eDataIntegrityReport.com

Confused by FERC’s sometimes vague compliance requirements? You’re not alone – FERC might be, too.

That’s the startling revelation we got recently from a man who ought to know: Randal Blanchette left the agency in September to join Abidance Consulting. At FERC, Randal was a cyber security specialist in the Office of Electric Reliability. He’s done audits on utilities large and small, and he’s seen it all.

“I was there at the creation” of the CIP 002-009 Standards, Randal adds. He’s uniquely positioned to help companies navigate these regulations, he argues, because he’s the only one involved at this level who has since left FERC. “Not to toot my own horn, but I understand what is happening and no one who has left FERC was in the position I was in,” Randal says.

So far, FERC’s efforts to provide more specific standards and requirements have been hamstrung by internal disagreements and an overarching desire to develop standards that “are defensible in court,”  the former FERC official says. That makes some sense, since a standard that won’t hold up in court loses a lot of regulatory teeth, Randal agrees, but that focus has sometimes made it difficult for FERC to offer much in the way of specifics. And it’s left a lot of regulated entities scratching their heads.

“The creation of the CIP 002-009 Standards by NERC with approval from FERC [presented industry with] many challenges of interpretive guidance as can be expected from an imperfect set of documents that catered to the lowest common denominator while simultaneously skimping on clarity for the entity players to understand,” Abidance Consulting’s James Holler has written on this blog.

“Many of the regulated entities I audited or came in contact with didn’t understand the ramifications of non-compliance” with the regulations, Randal says. Worse still, many thought they were in compliance when they actually weren’t.  “Many don’t have a good sense of what’s expected of them and how to comply.”

While regulated entities should get some sympathy for having to grapple with sometimes vague regulations, they still have to find ways to comply, Randal notes.

Making matters more complicated, Randal adds, is that there is a lot of “misinformation” out there in cyberland about what constitutes compliance proven reporting procedures.  Chatter and informal “advice” on the Internet is only adding to the compliance ambiguity faced by many regulated entities.

But there is some relatively good news, Randal says. The new CIP 010 and 011 standards are “more specific and helpful, but we’re still not there yet.”

Progress not perfection, as they say.

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How Access Card Readers are Becoming an “Achilles Heel” for NERC CIP-005 / CIP-006

James Holler, Founder, Abidance Consulting

Having conducted numerous Mock Audits and Gap Analyses for our clients, I am beginning to see a troubling pattern. A majority of the registered entities we have visited have failed to properly include the access card reader(s) on their Critical Cyber Asset list. This post will spell out in detail what NERC and FERC expect from a registered entity and most importantly, why.

As many of you know, access cards and access card readers are one of the main devices used to protect your Critical Assets and Critical Cyber Assets from the “bad guys”. While many registered entities employ this technology, most do not properly protect the one device that shields their assets from being tampered with. We are going to look at how the IP addresses assigned to your access card readers are not being protected and what can happen as a consequence.

If you have a card reader system for your Physical Security Perimeter (PSP) that has an IP address associated with it, you must include it in your Critical Cyber Asset list. Because the devices are “IP networked”, controlled, monitored and administered they need to be included as per CIP-002 R 3.1, when that PSP protects access to a control center, critical assets or critical cyber assets. To not include these devices is a finding during an audit that WILL lead to a FERC investigation, you can bet on that. If the card readers are not protecting any of the areas mentioned, then why even label them as part of the PSP? The purpose of a PSP is to protect and monitor access to critical assets in much the same way the ESP electronically protects and monitors access to critical cyber assets. This is the reason the language in CIP-005 and CIP-006 are so very similar. Better to err on the side of caution just in case the auditor is particularly astute on what FERC wants to be considered “compliant”.

Examples of what can happen if you fail to properly protect the access card readers are:

  • IP addresses can be used to fail the door or doors “open” – basically turning off the access card reader
  • IP addresses can be used to turn off the alarm portion of the card reader making it easy to access the CCA area without being detected for an undetermined amount of time
  • IP addresses can be used to back-track into the corporate network and do much more harm than just disabling an access card reader

You will definitely suffer a severe financial loss from the fine that will be issued when an auditor discovers this oversight.

This month we thought we would try something new. We are going to hold a conference call on October 1st at 2:30pm CST with our latest staff member, Randal Blanchette—the former lead CIP and ICP enforcer at FERC. For those who want to participate on this call and to ask Randal questions related to this and other CIP related subjects, please email us at james.holler@abidanceconsulting.com and put CIP Conference Call in the subject line.

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Interpretational Guidance on NERC's COM-001 Standard

James Holler, Founder, Abidance Consulting

James Holler, Founder, Abidance Consulting

During World War II the allies had some major challenges. Among the strangest was that the use of English by the Americans and British had many things in common, but also had many things different. As a result, there were problems in coordination, logistics and security.

Fast forward to 2006 and remember the creation of the CIP 002-009 Standards by NERC with approval from FERC. There were, and are, many challenges of interpretive guidance as can be expected from an imperfect set of documents that catered to the lowest common denominator while simultaneously skimping on clarity for the entity players to understand.

What does CIP-002 thru CIP-009 have to do with COM-001 you might ask? Plenty…the rule in the IT world is that you have an islanded or closed network (LAN) if you cannot use telecommunication hubs (like commercial carriers or satellite) to connect multiple sister nodes (other LANs) to create what is referred to in the network world as a WAN (Wide Area Network).

Let’s take a look at the Standard and see if we can make sense of it.

Let’s look first at the purpose statement COM-001. It says: “Each Reliability Coordinator, Transmission Operator and Balancing Authority needs adequate and reliable telecommunications facilities internally and with others for the exchange of Interconnection and operating information necessary to maintain reliability”

Notice two things, “reliable telecommunications facilities internally” & “with others for the exchange of Interconnection and operating information.”

This implies that the following requirements must meet these needs to be considered “compliant.” So, let’s look a little more deeply into the requirements.

COM-001 Requirement 1 and Requirement 1.4 states:

R1 Each Reliability Coordinator, Transmission Operator and Balancing Authority shall provide adequate and reliable telecommunications facilities the exchange of Interconnection and operating information:

R1.4 Where applicable, these facilities shall be redundant and diversely routed.

On the surface these requirements appear to be straightforward, but after a number of audits by FERC and NERC staff, it is anything but.

Both of these requirements would better be defined as simply nebulous. What defines “adequate”? “Where applicable”? Who decides what is adequate and where applicable…NERC, FERC or the Registered Entity that is being audited?

The auditor is the sole determining factor in compliance or noncompliance with these requirements. If they get it wrong, as many of them do, then you don’t have a compliant facility from a reliability perspective.

What R1, when tied to R1.4, says as it relates to the purpose is that if you only have one communications trunk entering your network and then have it multiplexed out to your Primary Control Center (PCC) and your Backup Control Center (BCC), you are not in compliance.

Another problem is that of the definition of what constitutes a telecommunications facility. It means different things to a telephone company technician and to an IT technician.

FERC and NERC define these to be BOTH data and voice traffic. You cannot simply have two phone lines and expect to be compliant if you are also doing data traffic from the PCC and BCC as part of your operations. You will fail the audit on this alone and fines are more than a possibility, they are virtually guaranteed.

James Holler is founder of Abidance Consulting.

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Achieve NERC CIP Compliance With Automated Security Controls

James Holler, Founder, Abidance Consulting

Complying with the NERC CIP requirements is expected to be a major expense for power producers and the like in the coming years. To date, companies have spent tens of millions of dollars to formally document and test the support for internal control assertions required by CIP and maintaining this documentation will continue to be costly beyond the first round of documentation.

Let’s take a look at some of the most important components of a good NERC CIP compliance program:

Automate The Testing & Reporting Of All Of The Technical Controls

An important concern for power producers is finding a cost-effective method of documenting, storing, and analyzing CIP control assessment work. Management is also looking to meet all the technical requirements spelled out in the requirements. In the first year, many companies have elected to use spreadsheets to tackle CIP documentation because they are familiar with the tool. Moreover, some companies prefer to use spreadsheets because the CIP requirements are still evolving.

Spreadsheets have significant limitations that will increase compliance risks. In addition, depending on spreadsheets for CIP documentation may prevent companies from improving their compliance process and risk management capabilities. In the first year of CIP compliance efforts, many internal auditors and project consultants have advised power producers to use their existing spreadsheet software to document compliance efforts. There is no way that these tools are sufficient to document all relevant accounts, account assertions, risks, controls, and deficiencies. The only way to truly document everything is to automate the process.

Use File Integrity Checks To Assure Your Systems Are In A Desired State

It is very difficult to compromise a system without altering a system file, so file integrity checkers are important. A file integrity checker computes a checksum for every guarded file and stores it. At a later time you can compute a checksum again and test the current value against the stored value to determine if the file has been modified. Some lesser quality file integrity checkers use a 32 bit CRC (Cyclic Redundancy Check). Attackers have demonstrated the ability to modify a file in ways that the CRC checksum could not detect, so stronger checksums known as cryptographic hashes are recommended.

One of the challenges in using a file integrity checker is the false positive problem. When you update files or apply system patches this changes the file. Creating the initial database of signatures is easy; keeping it up to date is much harder. However, even if you only run the checker once (when you first install the system) this can still be very valuable. If you are ever concerned that the system was compromised you can run the checker again to determine which files have or have not been modified.

The other challenge with a file integrity checker is that you have to have a pristine system when you create the first reference database, otherwise you may be creating cryptographic hashes of a compromised system while feeling warm and fuzzy that you are implementing good security. It is also very important that you store the reference database offline or an attacker may be able to compromise the system and hide their tracks by modifying the reference database.

Test System Configurations Against External & Internal Policies

Testing is an investigation conducted to provide stakeholders with information about the quality of the product or service under test. Testing also provides an objective, independent view of the configurations to allow the facility to understand the risks in the implementation of the configurations. Test techniques include, but are not limited to, the process of executing a configuration with the intent of finding “bugs”.

Testing can also be stated as the process of validating and verifying that the configurations:

  • meets the business and technical requirements that guided its design and development;
  • works as expected; and
  • can be implemented with the same characteristics.

Testing, depending on the testing method employed, can be implemented at any time in the development process. However, most of the test effort occurs after the requirements have been defined and the coding process has been completed. As such, the methodology of the test is governed by the configuration methodology adopted.

Testing can never completely identify all the defects within your configurations. Instead, it furnishes a criticism or comparison that compares the state and behavior of the configurations against principles or mechanisms by which someone might recognize a problem. These principals or mechanisms may include (but are not limited to) specifications, contracts, comparable products, past versions of the same product, inferences about intended or expected purpose, user or customer expectations, relevant standards, applicable laws, or other criteria.

A study conducted by NIST in 2002 reports that bugs cost the U.S. economy $59.5 billion annually. More than a third of this cost could be avoided if better testing was performed.

A primary purpose for testing is to detect configuration failures so that defects may be discovered and corrected. This is a non-trivial pursuit. Testing cannot establish that configurations functions properly under all conditions but can only establish that they do not function properly under specific conditions. The scope of testing often includes examination of configurations as well as execution of those configurations in various environments and conditions: does it do what it is supposed to do and do what it needs to do.

There are so many areas that can be addressed for automating that it would take dozens of pages for them all to be discussed. This blog was intended to give you a start on what you need to do if you truly want to ensure total CIP compliance.

James Holler is founder of Abidance Consulting.

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