News

HOUSTON (Feb. 2, 2021)

Cudd Well Control, a global onshore and offshore well control emergency response and critical well intervention provider, has entered into an alliance agreement with Worldwide Facilities, LLC, a national wholesale insurance broker, managing general agent and program underwriter.

For more than 45 years, Cudd Well Control has provided rapid well control response and engineering services to onshore and offshore Oil & Gas operations worldwide. Cudd Well Control is strategically located to quickly respond, prevent and mitigate critical well control events and reduce non-productive time.

Through this alliance and the insurance product administered by Worldwide Facilities, Cudd Well Control will be the preferred well control provider to the global Oil & Gas industry, giving companies immediate access to its experienced team of well control specialists, engineers and critical well intervention services. The alliance will actively support traditional Energy insurance products, in addition to the recently launched “Increased Costs of Drilling and/or Completion Insurance” (ICDC) Program.

Andy Ferguson, President of Cudd Well Control, stated “Being the ‘first call’ well control services provider under Worldwide Facilities’ upstream energy insurance policies is very exciting, and we are well-positioned for the task. We have the most experienced well control specialists and engineers and developed the latest in critical well intervention technology to provide our customers with the best well control services in the industry for the long term.”

Worldwide Facilities’ Matt Begnaud, SVP/Broker in Houston, TX, commented: “Cudd Well Control has positioned itself at the top of the well control, engineering and response marketplace with what we believe to be the most experienced team in the industry. This alliance furthers our commitment to continually develop products designed to address the most demanding risk transfer needs of our Oil & Gas clients.”

Bo Burris, Cudd’s Well Control Alliance Director, will lead the engagement and implementation of the alliance program, ensuring communication and engagement between the broker, claimant and Cudd Well Control. With more than 45 years’ experience, Burris is a pioneer in the creation and application of enhanced insurance recovery processes for the Oil & Gas insurance industry.

Media contact:

Sandra Flores
Director, RPC Marketing
sflores@cudd.com
(281) 719-2935

Excerpt from Permian Basin Oil and Gas Magazine – Dec. 20211

Cudd Well Control Vice President Dustin Locklear also observed that blowouts were down due to reduced drilling activity. Other services have fared better, however. “What we’ve been doing well on is the special service work: the hot tapping, the valve drilling, the freezes, lots of preventative measures like training, writing emergency response plans,” and more.

Immediately pre-COVID, in January of 2020, the company decided to reimagine and expand its well control service. They brought in Andy Ferguson as president of Cudd Well Control and Sam Bowden as vice president of Corporate Services for Cudd Well Control, along with Locklear, all of whom had long years of experience in the industry. They also hired about 15 of the best people from other companies, adding up to 800 years of total experience.

Next, they redesigned and remanufactured equipment they supply, and added new pieces to their offerings. A new, suitcase-sized hot tap unit is at the top of that list.

Behind the hot tap development was the realization that crowded pad-drilling sites required more compact tools, said Bowden. “It’s a very compact well base. You have wells that are very close together,” requiring smaller tools in order to access the well. The tool is “high pressure rated, but the real reason was some of these small cellars” at sites. Small size also allows it to be checked as luggage at an airport when a technician heads to a distant site. Some older units were so large they required an onsite crane for installation.

Generally a hot tap unit is called for when pressure must be released but a valve needed for that release is stuck shut. In that case the hot tap can safely drill a hole in the side for the installation of a new valve. Locklear explained that this is especially useful in plugging wells that were abandoned decades ago, whose valves have rusted shut. Some of those wells have no valves at all, only casing. A hot tap helps there as well.

The reboot came about with the help of RPC Inc. Cudd Well Control is a division of Cudd Pressure Control, which is a subsidiary of RPC. Ferguson said his goal upon assuming the GM reins was to improve the company’s people component. He recalled, “I met with Sam and with Dustin and we decided if we’re going to be in this business, we’re going to be in it for the long haul, and we’re going to have the best people, the best equipment. RPC let us do that.”

As the COVID shutdown hit a few weeks after that decision, Ferguson said, “It was either the worst timing or the best timing to do that.”

In the current environment, the market is picking back up, and all upgrades are ready for the increasing workload. With $75 oil and $5 per MMbtu natural gas they would like to see more business, but the market is also flooded with uncertainties that are holding back the implementation of new drilling projects.

One service on the rise is the plugging of abandoned wells, especially by the majors, Ferguson noted.

Locklear added, “Along with the plugging and abandonment comes the special service work—the hot taps, the valve drills. There are a lot of leaky wells around the United States. A lot of the majors are going in and fixing them now.”

Alliances with environmental companies allow Cudd to call them to remediate spills that result from blowouts, once the situation is stabilized.

SmartPhone App Arises During Downturn’s Quiet

“Another thing we did when we were all on lockdown,” said Ferguson, “[was that] we developed a Cudd Well Control app, available to anybody that wants it.”

When a customer has a wellsite event, that customer opens the app on their phone or smart device. The first thing that comes up is a button to click, which calls a Cudd well control expert. The screen also contains calculators for well control, coiled tubing, flange sizes, and other references. The app is also useful for quick access to non-emergency advice from Cudd personnel.

Well Control Insurance and Prevention

One new program is Cudd’s partnership with Worldwide Facilities, LLC, on an insurance program that covers up to $50,000 on services used in the first two days of a pressure control event. On the prevention side, it allows Cudd to offer rig surveys, training, and safety event drills.

In a separate program, Cudd now offers wellhead surveys wherein they test field equipment for wear and tear, rating sites on a scale from safe to dangerous. This can be done for drill, frac, or production sites. With all the advantages brought by total site automation, Locklear noted that there is one disadvantage. Some problems, potential or current, can only be detected by human eyes or direct evaluation. Site surveys, somewhat like a season preventive maintenance visit for a home HVAC system, make a site even safer.

Pad Drilling’s Effect on Well Safety

A blowout on a single-well pad is dangerous enough, but the recent trend toward multi-well pads has exponentially increased the safety issues to be considered. In that light, Cudd has recently completed two studies examining the potential impact when one rig on a pad has an issue—such as falling over onto another well or wells—and how that could cause additional emergencies. They have also studied the effects of radiant heat, and how heat from a fire on one well could ignite others.

For example, Bowden recalled, “Year before last, we were on a four-well pad where one well caught on fire and it simultaneously caught the next, and the next, and the next well on fire.”

From the studies the company has advised producers on pad redesign to reduce risk and to better accommodate emergency efforts.

The 21st century well control company spends much more time and effort in prevention and planning than in dramatic catastrophe control, although they are fully ready to do that when needed. As John Wayne’s shadow disappears in the distance, it’s replaced with the shadows of thousands of workers heading home safely at the end of a shift.

Less dramatic, maybe, but much more satisfying to the community.

Media contact:

Sandra Flores
Director, RPC Marketing
sflores@cudd.com
(281) 719-2935

Special Report from American Oil and Gas Reporter – Dec. 2021

With drilling and completion work ramping up, companies in all segments of oil and gas hanging “help wanted” signs outside their front gates, and inflationary cost pressures intensifying across the board, the industry is approaching 2022 with renewed optimism tempered by the awareness that managing business risk is important as ever.

Industry trends certainly point in the right direction, but increased activity equates to greater risk exposure; new hires mean unseasoned personnel on the well site; and higher costs translate to greater economic consequences if something goes wrong.

Well control specialists offer theses bits of advice for operators and contractors: Train relentlessly and call early. The sooner the experts get involved, the lower the cost and impact of potential well control incidents. Oil and gas insurance experts have similar advice: Call often to make certain insurance programs are regularly reviewed and updated to keep pace as oil and gas activity levels change.

Biggest Risk

Cost pressures-especially margins on shale well development projects-may be a key determinant in whether mangers pick up the phone at the first hint of trouble or try to work through a potential well control issue. Rick Burns, senior vice president at Amwins Program Underwriters, says there is a solution for operators that worry about spending unplanned capital outside the budgeted authorization for expenditure to drill and complete a well.

“We now have an incentive for them to call the well control expert: Underwriters will, up to a certain amount, pay for the response, so there is no initial cost impact to the customer,” Burns says. “Now, the burden is taken off his shoulders. The customer does not have that profitability issue weighing against the well control risk. This is fairly new, and it will be as standard as all insurance in the future. It is only a matter of time.”

Cost control is even more essential as insurance pricing ticks up after seven years of a soft market in which every renewal of operators and nonoperators included rate reductions, he says. Now capacity that was once overabundant on the insurance side has dwindled from the extended soft market and is compounded by lease operator mergers and acquisitions. The impact of these factors result in well control insurance costs rising 15% – 25%, Burns says.

As market conditions change, insurers and well control specialists continue to look for ways to help operators and contractors mitigate risks, he adds. Under a new alliance agreement between Cudd Well Control and Amwins Program Underwriters, customers of the wholesale insurance broker, managing general agent and program underwriter have access to Cudd’s well control specialists, engineers and well intervention services under an arrangement that should speed communications and claims services, Burns says.

About 25 years ago, Burns and Bo Burris, Cudd’s well control alliance director, launched a program between Lloyds of London and Burris’s previous well control firm in one of the first arrangements of its kind in which the well control company agreed to provide engineering and risk management services to help prevent blowouts, Burris recalls.

Under the current arrangements, well control experts provide a menu of training, audit and additional risk management services designed to prevent a blowout or minimize the impact of one, he says.

Specialists can perform rig, frac spread, coil tubing and snubbing audits in which experts make trip to the field to examine equipment and processes with their representatives to help ensure functionality when needed, Burris says.

Cudd also offers well plan reviews, emergency response reviews, well control response plans and well site contingency training.

As activity increase, an influx of inexperienced workers poses the biggest well control risk, Burris suggests. “When you have a downturn and lose guys that have 35 – 40 years of experience, you have a gap,” he explains. “It happened in the 1980s downturn and two others in between. It is problematic and we are going through it again right now.”

In any environment, personnel is always the primary issue in well control and mitigation, especially now that more land, Shelf and deepwater rigs are going back to work, says Larry Nixon, senior technical advisor at Cudd Well Control.

“During this time, all of the drilling, workover contractors and service companies are trying to respond to these needs, but the risk lies with people,” he continues. “You can have the best equipment, the best drill ships, best land rigs, but you have to have good quality, well-trained, experienced people.”

To help address training and preparedness, Cudd performs a crew awareness program that evaluates the drilling rig crew and helps contractors shore up training deficiencies. Cudd Well Control also has a well control certification school for intensive well control training and risk mitigation, with company operations overall supported by veteran company specialists and engineers who were trained by the likes of Bob Cudd, Joe Bowden Sr., Red Adair, Boots Hansen, and other industry notables, Nixon says.

In addition to mitigation, having sufficient insurance coverage is essential to helping operators manage well control incident costs, Burns advises. Policies have been consistent over the years and include three sections that cover the cost to control the well, the cost to re-drill or restore the well to its prior condition, and the cost from damages and clean-up of any seepage or pollution from the well, he says.

Despite consistent offerings, every operator needs to thoroughly examine the definition of a well out of control and the definition of an underground well out of control in any policy, Burns insists.

“Those are the two main coverage triggers,” he explains. “If you do not have an event that meets that definition of these triggers, you have no coverage for all three sections. It is paramount that operators look at the wording and get the broadest wording available there.”

Changes from the advent of unconventional upstream operations created the need for additional endorsements, including the multiple-well pad endorsement, Burns points out.

Multiwell pad drilling activities have brought additional risks. Well control contractors have helped build industry understanding of those risks through education and preparation for events, but dissemination of information about solutions and lessons learned needs attention, Nixon says.

“We do a great job in our industry, but we still need to work on informational sharing on well control events,” he assesses.

As well numbers on pads have increased to as many as 10, Cudd works to get with customers ahead of time to discuss things such as cellar design, cellar type, cellar depth and types of wellheads, all of which will affect the response and aspects of the resolutions, Nixon says. Familiarity with pad layout, wellheads and tree cascading escalation, Nixon remarks.

On multiwell pads, lessons learned include how to avoid having all casing valves facing one another, Burris say.

About a decade ago, a well fire ignited six wells in a cascading effect because of the casing valve placement, he recalls.

In policies, multiwell pad endorsements were created to clarify coverage during incidents involving several wells on a pad, Burns points out. Multiwell blowouts on a single pad are one occurrence, which demonstrates the need for higher limits and more coverage, he adds.

With work contracts typically spelling out whether operators or contractors are responsible for various types of coverage, gaps in coverage are not an issue but duplicated coverage by happenstance is, Burns says.

Best Practices

Operating companies can adopt best practices to mitigate risks in addition to well plan reviews on high-risk wells. Burris suggests having two qualified drilling supervisors work day and night shifts during critical sections of a well to provide 24/7 operational surveillance and avoid having a single supervisor who can become sleep-deprived, which can complicate decision-making.

During drilling, frequent directional surveys with a gyro or magnetic multishot too can help identify the bottomhole location throughout the process. Knowing the bottomhole location helps target relief wells quickly during a blowout, Burris say.

After rotating a well for a long period, metal cuttings can be indicative of weakened casing, Nixon points out. Casing shoes need to be tested to leak-off or perform a formation integrity test one pound per gallon above the anticipated mud weights.

Cutting corners during shoe testing often leads to problems, as does impatience when waiting for cement to reach acceptable state and compressive strengths, Burris warns.

“A large percentage of past well blowouts have occurred when people got in a hurry after cementing casing and failed to wait long enough for the cement to set,” he says.

Best practices are essential when using oil-based muds, Burris emphasizes. Cudd has responded to a number of blowouts in which gas carried in oil-based solutions expanded rapidly at bubble point and caused a blowout.

In the unconventional oil and gas world, most emergency response calls involve completion, workover or production activities more than drilling, Nixon states.

To prevent escalation in any well event, operators should contact well control specialists when issues seem small, Nixon advises.

“If you have a small problem, typically it is not going to get any better if it is a leak,” he says. “We have seen instances where if the customer had called earlier and we could have gotten there sooner, we may have been able to prevent escalation. Customers are in the business of producing oil and gas. We are in the business of solving problems and it’s typically not within their expertise to address these types of issues.”

A potential future problem area could involve drilling deep conventional oil and gas wells because of a serious lack of experience drilling deep, high-pressure permeable environments, Burris Considers.

And while company cultures dictate the importance of well control coverage, investors are now demanding that more stringent well control and mitigation standards be embraced, he says.

“We are trying to understand what our customer needs are,” Nixon offers. “What I like to ask all customers, whether the representative in the field or the chief executive officer, is: What keeps you up at night in regard to well control and how can we help?”

Media contact:

Sandra Flores
Director, RPC Marketing
sflores@cudd.com
(281) 719-2935

Around the world, myriad onshore and offshore oil fields are reaching the end of their productive lives. According to the Environmental Protection Agency, 3.2 million abandoned oil and gas wells exist in the United States. Included in these are thousands of wells drilled more than half a century ago that were not properly plugged and abandoned, Fig. 1.

This is not just a challenge for the U.S., but a global one as well. Wells in the Arabian Gulf, the North Sea and the Caspian Sea, as well as most other offshore areas of the world, are part of this trend. As a result, operators face an upcoming “P&A wave” of wells that need to be permanently plugged and abandoned.

Onshore of Offshore

Whether onshore or offshore, the reasons for P&A are the same. These include:

• Lack of well delivery — The well is no longer productive
• Well problems — Making it not economical for recompletion or doing a workover
• Environmental concerns — Cleaning up the area and not wanting to operate in certain places
• Structural issues — Due to age or hurricane damage.

From Old Problems…

This proliferation of current and future needs presents unique challenges for operators and well control companies. An abandoned well may present a conduit to the subsurface aquifers below. One abandoned well could contaminate groundwater for miles. Abandoned wells can contaminate groundwater, emit volatile compounds, and leak methane. In the case of older wells, the operation is even more complex, because detailed records of how the well was completed or previously P&A’d or abandoned might not be available. This means operators and service companies must try to determine what is happening underground, based on records of nearby wells. If a well was abandoned decades ago, crews might need to build roads to move the equipment required for the job. Operators are already putting huge efforts into making sure that both older wells and newer wells are abandoned properly. However, they are up against unprecedented challenges. For example, there are thousands of orphan oil wells with no leaseholders, and which were originally drilled decades ago when there weren’t strict regulations to follow, to make sure that wells were properly plugged, Fig. 2. In addition, record-keeping was done on paper, so there is no reliable way to get accurate data on the original P&A or know what awaits a Well Control company about to perform a new P&A.

…To New Problems

As a rule, the Well Control business is 75% workover, completion and production. However, over the past two years, the P&A aspect has become more of a focus for U.S. operators and has taken a larger share of business. In the past 10 years, operators began drilling multi-well pads, which are relatively new in the overall scheme of things. But within 10 more years, we will have multi-well pads that are 20 years old that present a whole new set of P&A challenges. What we do today regarding drilling and production is going to dramatically impact how we do P&As down the road.

For example, drilling and production pads in the Marcellus and Utica shales in the Appalachians are more confined and congested, and everything is tight, which could make the P&A procedure more difficult than previously. What’s more, these wells may be double-valved on the higher pressure rated annuli wellhead assemblies. So, you may not be able to access a valve horizontally, due to cellar design and well spacing. Instead, a right-angle solution for valve drilling is needed to solve the issue. Well spacing, and valve and tree alignment, present a chance for collateral and cascading damages, should a blowout occur, producing a horizontal jet flow and/or fire. Offshore also poses unique challenges, due to space limitations and wellhead valve and tree alignment, as well.

Compounding these hurdles is the fact that there are fewer qualified companies out there with the skills and experience to perform P&As with these issues. The bottom line is that more than ever, P&As require service from well control companies with the specialized skill sets, knowledge bases, tools, and technologies.

Reducing P&A Risk Upfront

The well control community needs to do a better job of communicating possible solutions to customers, to helpeliminate concerns. Wells can change hands multiple times in the courses of their lives and because of that, many customers are facing unknown well integrity issues.

Well control company-assisted well integrity programs can make a huge difference in helping the customer avoid needless problems and expenses when P&As are needed. The idea is to help customers substantially reduce risk by involving a well control company in the planning stages of a P&A, so customers are aware of their vulnerabilities before beginning operations, Fig. 3.

With contingency plans in place prior to the P&A, customers can substantially mitigate any types of exposure and reduce costs.

Creating a Smarter Approach To P&As

Operators are in the business of drilling and producing, not P&A. Typically, operators don’t have the manpower or resources required to perform a P&A—especially one with issues—and don’t have the staff to dedicate to P&A. It’s also important for customers to have all the products, services, and technology to meet the complete needs of a P&A.

For example, our bundled services from cementing to coil, to downhole tools, engineers, flowback tanks, hot tap, valve drilling, freeze services, etc., fill the gaps of traditional service companies to perform a P&A, Fig. 4. There is one contact that makes it easier for customers to handle the project from start to finish. The fewer contracts that customers must deal with is smart for both financial and efficiency reasons. They don’t have to worry about the liabilities of using 10 different companies, 10 different insurances, 10 different safety cultures, and 10 different pricing practices. Instead, they have one provider to meet their complete P&A needs with the products, services and technology required to be prepared for the unexpected.

Ensuring Well Integrity with Technology

The detailed operations required in a P&A can vary significantly from well to well, depending on the type of well and the actual well conditions. A critical part of P&A is assessing well integrity prior to an abandonment. Technology plays a major role in this. For example, we have a mobile Wellhead Audit application that inspects wellheads and identifies in minutes which wells need immediate attention and which wells are of minimal or moderate risk. This is a highly efficient way for customers to know whether their assets present risk and take steps to rectify the issue before the risk becomes an unwanted issue that can escalate. Technologically advanced hot tap, valve drilling units and freezes may be a key to the P&A preparation process, depending on the well, Fig. 5. Today’s valve drilling machines are lighter and more efficient than previously available. Freezes are now being performed with field people. These folks are engineers that continually improve technologies and are coming with solutions to handle congested well bays, and lack of horizontal and vertical access on offshore structures.

In the area of hot taps, Cudd Well Control has developed a new ultra-compact Hot Tap that is less than 10% the weight of conventional equipment, and the only hot tap on the market rated API 6A 3G. This highly safe technology, used to check pressures, offers a compact design that makes it easy to transport and easy to use by one worker.

Stepping Up to the Challenge Together

Plugging and abandoning the scores of orphaned oil and gas wells presents an opportunity to mitigate problems and potential risks, and provide an economic boost to the experts that specialize in this area. Employment gains from plugging wells could help offset job losses from the oil and gas industry, which lost tens of thousands of jobs during the Covid-19 pandemic. While there is much work still to be done on the issue, a concerted effort by the Well Control community is a promising step to meeting the environmental and economic goals of customers around the world.

Media contact:

Sandra Flores
Director, RPC Marketing
sflores@cudd.com
(281) 719-2935

HOUSTON (AUG 3,2022)

Cudd Well Control today announced the launch of its new Wellhead Audit inspection platform. Developed by Cudd’s in-house engineering and technical experts, this advanced tool leverages the power of the Cloud in a patent-pending process that brings unprecedented efficiency, traceability, and accuracy to wellhead audits. This revolutionary platform is the first of its kind in the industry. Fig. 1.

“Part of the CuddAssured™ brand, the Wellhead Audit platform emphasizes our commitment to expanding our portfolio of technologically advanced solutions, and it’s a perfect way to mark our 45-year anniversary,” said Andy Ferguson, President, Cudd Well Control. “Whether you’re buying or selling wells or executing regular maintenance programs, it is imperative to know the conditions of your wells and the risks associated with them. This cloud-based system is new for the well control business and a game-changer that provides unparalleled asset protection as well as safer and more reliable operations.”

A Single Platform for Multiple Wells

By using this efficient tool with its automated, immediate reporting, operators can quickly see the condition of their wells, including any problems with corrosion, valve functionality and pressure, on one platform and have a preliminary report on site the moment the audit is done. As a result, what used to take a few days to complete can now be accomplished in less than an hour. Ideal for production wells or storage wells, the Wellhead Audit tool is fully customizable to each customer’s operational requirements.

“For customers with wells in remote locations, the tool allows them to complete more audits in a day and have that information at their fingertips immediately,” said Bhavesh Ranka, P.E. Operations Manager/Sr. Well Control Engineer. “What’s more, its traceability and tracking capabilities allow customers to identify trends that may negatively impact their operations and take proactive measures to avoid any issues.” Fig. 2.

“We saw the opportunity to give our customers advanced awareness of a well’s potential issues,” said Dustin Locklear, VP of Cudd Well Control and partner in the development of this platform. “Our dashboard categorizes the risks so that operators can prioritize and address problems early, before they escalate to a more critical condition.”

Conducted by Proven Well Control Professionals

All inspections with the Wellhead Audit platform are conducted by the same knowledgeable and experienced Cudd employees who deliver well intervention services across a range of applications for even the most demanding environments.Fig. 3.

More About Cudd Well Control

For 45 years, Cudd Well Control has been an industry leader in rapid well control response and engineering services worldwide. Our rich history, tradition and experience continue to drive our people to provide superior services across all well phases. With our best-practices approach, you will receive 24-7 access to world-class well control engineering along with expert training to ensure operational excellence and reliable performance.

Media contact:

Sandra Flores
Director, RPC Marketing
sflores@cudd.com
(281) 719-2935

New state-of-the-art facility consolidates office space with warehouse in one location

HOUSTON, TEXAS – After a year-long planning and construction phase, Cudd Well Control today announced the unveiling of its new global headquarters. The 27,000-square-foot state-of-the-art facility expands Cudd’s presence in the Greater Houston Metroplex and consolidates the company’s offices and warehousing in one location. This new base of operations underlines Cudd’s growth strategy as it celebrates 45 years of operations, develops new technologies and a powerful well control workforce.

“In the past year, we’ve invested in technology, built strong alliances, grew our team, and now we are physically expanding our footprint with the new headquarters in the greater Houston area,” says Cudd Well Control President Andy Ferguson. “The new facility will improve efficiency, collaboration, and offerings while providing an exceptional work environment for our employees and our customers.”

The new facility offers the space to hold advanced well control training on-site and act as an emergency response center for customers. Furthermore, the facility’s grounds feature a retention pond where Cudd’s well control equipment can be demonstrated and seen in action. An additional laydown area at the facility also allows Cudd to invite its sister companies to showcase their industry-leading equipment and service lines to customers.

With both the office and Cudd’s equipment now in the same location, customers will have a one-stop destination for their well control needs and will save travel time. Internally, Cudd will benefit from increased communications and efficiencies between departments, further accelerating the company’s response time.

The new headquarters offers an inspiring working environment for Cudd Well Control employees and sets the course for further growth. Integrating technology, solutions, and people, the facility is poised to deliver the future of well control today while acting as the central hub supporting other critical regions that house Cudd’s newly updated emergency packages and equipment.

Located in Hockley, Texas, the new global headquarters offers proximity to George Bush International Airport and David Hooks Airport, where Cudd personnel fly from when called out on emergencies. The site is also conveniently accessible via major Houston area freeways, including Texas State Highway 99 and U.S. Highway 290.

Cudd Well Control New Global Headquarters:
22242 FM 2920, Hockley, TX 77447

Media contact:

Sandra Flores
Director, RPC Marketing
sflores@cudd.com
(281) 719-2935