Assembly Tip: Inserting Slips into the Anchor Housing

The many benefits of running a Slimline® Tubing Anchor Catcher are realized, in large part, thanks to the anchor’s reduced OD. However, when it comes to assembling the TAC, that smaller OD can create some pretty tight spaces. In particular, without the right technique, inserting slips into the anchor housing can lead to some frustration and colorful language.

In the video below, TechTAC’s Midland Regional Manager Weston Hendricks demonstrates the ideal way to insert slips into the Slimline® housing. Do you have other assembly tips you could share? Record yourself demonstrating the tip (less than 1 minute) and send it to [email protected]. Every tip that gets published on the TechTAC® blog earns the sender a $75 Amazon gift card!

2024 TechTAC® Product Catalog Available Now!

The latest TechTAC® Product Catalog is now available as a digital download or in hard copy at any TechTAC® office.

The new publication is an ideal reference for oilfield equipment dealers, offering a comprehensive overview of TechTAC’s complete line of tubing anchor catcher solutions. Those solutions are designed to support service companies in addressing a myriad of downhole challenges.

“TechTAC® is committed to building lasting relationships with service companies and helping them support the needs of engineers and field personnel, no matter the downhole challenges they face,” said TechTAC® CEO Brad Crist.

“As you’ll see in this catalog, we offer a wide range of tubing anchor solutions – from the patented Slimline® Tubing Anchor Catcher and Slimline® QuickSet™ TAC to standard B2 TACs to custom tools that can navigate casing patches – to give engineers and operators maximum flexibility in designing and running downhole tool assemblies.”

The printed version of the TechTAC® Product Catalog is a durable booklet that provides a convenient reference for TechTAC® products, part numbers, custom tools and more. Contact your local TechTAC® representative to get a printed version of the catalog.

Download the digital version by clicking on the image below.

TechTAC product catalog cover

An Introduction to the TechTAC® Slimline® Tubing Anchor Catcher

In this 90-second video, learn how the unique and patented design of the Slimline® Tubing Anchor Catcher allows sediment and formation gas to flow around the anchor instead of creating a choke, as is common with a standard B2-style anchor. In turn, the Slimline® helps mitigate the risk of downhole challenges like scale formation and rod pump gas locking.

In wells with sucker-rod pumps, tubing anchor catchers, or TACs, can stabilize the production string.

However, standard B2-style TACs, along with other traditional anchor designs, are also susceptible to several common problems that can hinder production.

Because the annular area between the TAC and well casing is so small, sediment and scale can bridge-off on top of the anchor and cement it in place, often resulting in an expensive fishing job. At the same time, the TAC essentially acts as a choke, trapping formation gas below the anchor, leading to a gas locked rod pump.

In contrast, the TechTAC® Slimline® Tubing Anchor Catcher provides up to 245% more flow-by area between the anchor OD and the casing ID.

According to an independent CFD study, that increased flow-by area means the Slimline® creates far less pressure drop, turbulence and turbidity than a standard B2 anchor.

CFD comparison of tubing anchor catchers

That free flow of fluid helps mitigate the frequency and impact of stuck anchors and gas locking, which in turn can help operators significantly reduce costs and increase production.

To learn more about the TechTAC® Slimline® TAC, or to get a quote, contact the TechTAC® team today!

Petroleum Engineer Bruce Friesen Breaks Down the New CFD Study

“There are multiple benefits of running the TechTAC Slimline anchor. Number one, reduce pressure and temperature drop, reduce turbidity and turbulence, which all four of those things contribute and cause the formation of scale, iron sulfide, paraffin and solids. [Eliminate] all those parameters … then you don’t have plugging. You don’t have stuck anchors. You don’t have workovers. You don’t have fishing jobs. And you also don’t have what is one of the biggest issues and problems and headaches in the oil patch is gas locking of your rod pump.”

That’s just one of the key takeaways for Bruce Friesen, former global artificial lift advisor for BP, from his review of a new computational fluid dynamics (CFD) report that compares the performance of two different types of tubing anchor catchers: TechTAC’s patented Slimline® TAC and a standard B2-style anchor.

Watch Bruce break down the rest of the results in this quick 3-minute video:

To receive a complementary copy of the CFD report, visit the report download page.

What to Check Before Running an Anchor Downhole

When a TechTAC Authorized Dealer receives an assembled anchor, the accompanying packing slip includes several notes. One of them reads: “Tools are to be checked upon delivery to ensure they are in correct working order.” But what does it mean to “check” the anchor? While individual circumstances may vary, this post will highlight a few key items that should be inspected before running an anchor downhole.

A Focus on Quality

Assembling a Slimline TAC

One of TechTAC’s core values is to always meet the highest standards of quality. Whenever a tubing anchor leaves one of our facilities – whether a patented Slimline® TAC or a standard B2 anchor – dealers can trust that product has been built according to key quality standards. Those standards include using American-made steel and following a best practice assembly procedure.

Before Running an Anchor Downhole

However, once the anchor leaves a TechTAC® facility, it can encounter conditions that may damage or otherwise prevent the tool from being ready to run in a well. Unexpectedly harsh road conditions during shipping are one example. Others could be how the anchor is unloaded or how it is stored. Even the dedicated team at TechTAC® is still human and may occasionally miss doublechecking the tightness of an anchor sub. For those reasons, performing a few simple checks before the anchor leaves a service company’s shop is important:

  • Tighten Subs to Customer Requirements –When the TechTAC team assembles an anchor, the top and bottom subs are firmly tightened to industry standards. However, every customer is different and may have higher or lower torque recommendations. With that in mind, anchor subs should always be checked and tightened to specific customer requirements.
  • Cycle the Anchor – To ensure proper actuation of the slips when the anchor is downhole, it’s important to cycle each TAC before it’s delivered to a well. That means manually turning the body to verify the slips fully extend. With the Slimline® and B2 anchors, the TAC is usually fully set in 6-to-8 turns. With the Slimline® QuickSet™, 1-to-3 turns are typically required.
  • Tighten Exterior Bolts and Screws – In addition to tightening subs and cycling the anchor, it’s best practice to also tighten any exterior screws.
Tubing anchor assembly

Ensuring Optimal Anchor Operation

Most of the time, these checks won’t reveal any issues. But establishing a consistent quality assurance process for every anchor can minimize the risk of future challenges. To learn more about ways to optimize the performance of TechTAC® anchors, check out the product resources page.

Setting a Tubing Anchor: One Commonly Missed Step

To ensure the optimal downhole performance of its tubing anchor solutions, TechTAC® has established best practice guidelines for setting a tubing anchor. Some of these guidelines are simple cautions, such as avoiding carrying an anchor by the drag springs. Others are vital to its proper operation.

View the complete Setting & Releasing Instructions.

An Important – and Commonly Missed – Best Practice

Though uncommon, rig operators may encounter an anchor that accidentally releases or won’t fully set. This issue can often be linked to missing one important best practice that’s noted in those Setting & Releasing Instructions. In the “Setting the TAC” section of the document, items 4 and 5 say:

The tubing will torque up when the slips have set. To ensure all tubing torque works its way down to the tool, maintain left-hand torque and alternate several times between setting down and pulling up.

During this slip-setting operation, the strain pulled should be at least equal to the final strain that will be applied when the tubing is landed and full set-down weight should be applied.

In other words, it’s essential all the tubing torque reaches the anchor. Moving the tubing up and down ensures the torque can make it past any tight corners. This technique is especially important in deep, deviated or corkscrewed wells. However, it should be applied in any well where a TAC is set.

Oil rig worker with hydraulic wrench

One More for Good Measure

As an added measure to help prevent a TAC from backing off during pump operation, once the slips have set, the rig crew should hold tension for at least 2 minutes to ensure the slips permanently bite the casing. Then put an additional 1/2 – 3/4 turn in the tubing immediately before landing it.

Best Practices for Setting a Tubing Anchor Ensure Benefits are Realized

Following the guidelines for assembling, setting and releasing the Slimline® TAC not only prevents troublesome issues, but it also ensures the numerous benefits of the Slimline® will be realized downhole. Thanks to a patented design, the Slimline® anchor provides up to 245% more flow-by area than a conventional TAC. With that increased flow area, the anchor is far less likely to create turbulent flow and pressure drop as fluid passes around it. In turn, the risk of scale formation or a gas-locked rod pump is greatly reduced.

To learn more or get a quote for the Slimline® TAC, contact the TechTAC® team today.

What It’s Like to Cut Over a Slimline® TAC

Summary: TechTAC® Director of Product Management Luke Reary explains the process for cutting over the patented Slimline® Tubing Anchor Catcher

While the unique design of the patented Slimline® TAC helps to greatly diminish the number of stuck anchors production companies have to remove, like any piece of downhole equipment, the Slimline® may occasionally need to be cut over.

In this video, taken from a recent Tech Talk with the Society of Petroleum Engineers, TechTAC’s Director of Product Management Luke Reary explains why the cut over process is faster and easier with a Slimline® TAC, compared to a standard B2 anchor.

For more information about TechTAC’s range of downhole tubing anchor solutions, or to get a quote, contact the TechTAC team today.

New Downhole Fishing Guide Available from TechTAC®

Summary: Rig crews can use this new document to reference key measurements and specifications for both the Slimline® TAC and standard B2 anchors sold by TechTAC®.

An oil rig

Sometimes a fishing job can’t be avoided.

A damaged casing, scale buildup, a stuck anchor, equipment failure and more can require a rig crew onsite to get things “unstuck” and producing again. While the unique design of the TechTAC® Slimline® TAC can mitigate the risk of many of these issues, if problems do occur, it’s helpful if the fishing crew can understand the precise measurements of the downhole equipment.

With that in mind, TechTAC® has published a new Downhole Fishing Guide. This resource – available in digital format and hard copy – includes diagrams and measurements for 11 of TechTAC’s most popular anchors, including both Slimline® TACs and standard B2 anchors. In addition to basic measurements, such as anchor OD and ID, the guide also includes unique measurements that are especially helpful during a fishing job. For instance, the distance from the cap to the end of the mandrel (body) is noted for each anchor.

The printed version of TechTAC’s Downhole Fishing Guide is a heavy-duty tri-fold brochure that can be easily stored in the glovebox of a vehicle or pinned on a wall in the shop. Contact your local TechTAC® representative to get a printed version of the guide.

Download the digital version by clicking on the images below.

Downhole Fishing Guide inside
Downhole Fishing Guide outside

TechTAC® No Longer Charging an Assembly Fee on Tubing Anchors

Summary: As of March 1, 2024, TechTAC® will no longer charge a fee for the assembly of tubing anchors. The move gives customers a simplified purchase process and more value every time they engage with TechTAC®.

No assembly fee on tubing anchors

TechTAC® is making a change to simplify the purchase process and deliver more value to customers. As of March 1, 2024, the company will no longer charge a fee for the assembly of tubing anchors. This pricing change applies to all sizes of TACs, regardless of the quantity purchased.

“While the actual dollar amount is minimal, we found that charging a separate assembly fee on tubing anchors could create some friction in the ordering process, particularly for large shipments, so we wanted to eliminate that issue,” said TechTAC® CEO Brad Crist.

TechTAC® operates according to a set of core values. One of those is to actively listen to its customers and seek to earn their trust with every interaction. Simplifying the ordering process by waiving the assembly fee on all anchors is one of those points of feedback the company has heard repeatedly from customers. This change is the result of those discussions.

Many of TechTAC’s Authorized Dealers will prefer to continue ordering anchor parts and assembling the TACs themselves. However, waiving the assembly fee gives those dealers another option to stay ahead of the needs of their operator customers.

A Variety of Downhole Tubing Anchor Solutions

Anchor assembly at no additional charge is available for TechTAC’s standard B2 anchors and the company’s patented Slimline® TAC. Many operators and service companies have standardized on the Slimline® TAC for their downhole assemblies because it provides up to 245% more flow area than the standard B2 design.

A recent computational fluid dynamics (CFD) study found that with that increased flow area, the Slimline® creates far less pressure drop and turbulence, as fluid and gas flow around the TAC, than a traditional design. Wells that experience less pressure drop and turbulence are much less likely to encounter plugging and gas locking.

In the unlikely event that a Slimline® TAC does get stuck in a well, the anchor’s unique design allows it to be cut over in far less time than a standard B2 TAC. Due to the smaller diameter, only the slip protectors and slips need to be cut over.

Workover rig

One completion foreman with a U.S.-based oil and gas company saw this reduced cut over time firsthand. He said, “Some of our wells were producing a lot of sand, so the anchors were getting sanded in. Standard anchors would take several hours, and sometimes days, to cut over. The Slimline TAC is completely different. It took longer to assemble the power swivel than it did to cut over the Slimline anchor. Less than 20 minutes.”

Quality and Value in Every Product

While the Slimline® TAC is an ideal choice for many downhole assemblies, some operators will prefer to continue using the traditional TACs they’ve used for many years. That’s why TechTAC® offers both. Both product lines are sourced and manufactured in the United States to ensure they meet the highest standards of quality. And now, there is no separate assembly charge for any TACs – giving customers a simplified purchase process and more value every time they engage with TechTAC®.

The Economic Impact of Oil and Gas

Rod pumps at sunset

The Texas Oil & Gas Association (TXOGA) recently released its Annual Energy & Economic Impact Report for fiscal year 2023. The purpose of the report is to provide an update on the industry’s global energy leadership, environmental progress and policy priorities. Among many data points highlighted in the report, one of the most significant highlighted the industry’s contributions to state a local economies.

According to the report, “The Texas oil and natural gas industry paid a record $26.3 billion in state and local taxes and state royalties in fiscal year 2023, shattering the previous high by more than $1.5 billion.” Those contributions help to fund everything from local schools to state infrastructure and improvement projects.

Many of the key points from the report are summarized in this infographic from TXOGA:

TXOGA infographic

TechTAC’s Patented 7 5/8-inch Slimline® Anchor Has an Improved Assembly Process

Summary: TechTAC offers its patented Slimline® TAC in many common and custom sizes. The largest of the conventional sizes is the 7 5/8-inch anchor, which has been improved for faster assembly. Regardless of size, however, the design of the Slimline® provides several significant benefits. In particular, its increased annular flow creates less pressure drop and turbulence than a standard B2 TAC.

Palettes of Slimline TACs

“We strive to offer the highest levels of customer service by exceeding our customers’ expectations.” That statement is one of TechTAC’s core values. Among other things, it means we aim to provide service companies and operators with the downhole tubing anchor solutions they need, when and where they need them.

To provide that level of service, TechTAC® offers a variety of the most common tubing anchor catcher (TAC) sizes. The largest of these is our 7 5/8-inch (7.625-inch) anchor. That tool is available in both a standard Baker B2-style design, as well as the patented Slimline® design. As with other TechTAC® products, most orders for 7 5/8-inch anchors are either delivered or shipped within 24 hours.

A New Slip Design for Easier, Faster Assembly

Assembling a large piece of downhole equipment like the 7 5/8-inch Slimline® can be challenging. The size of the tool and the relative size of its components can create some tight workspaces. In the past, the height of the 7 5/8-inch Slimline® slips compared to the limited space in the anchor’s housing could slow the assembly process. Only two slips could be inserted initially. The third would have to be connected to its springs from within the housing. Great tool but not the easiest to put together.

To make the assembly of the 7 5/8-inch Slimline® faster, TechTAC® has improved the design of those slips. The new design, similar to the 4.5-inch Slimline®, features a two-piece slip. The bottom section of all three anchor slips can be inserted into the housing, and once they are positioned, the top sections quickly slide into place. The faster assembly process for TechTAC’s largest Slimline® anchor is just another way the company tries to deliver the right anchoring solutions as quickly as possible.

Downhole Tubing Anchor Solutions to Fit Most Wells

Customers looking for other sizes of tubing anchors can choose from TechTAC’s wide variety of conventional and custom products:

Slimline®
TAC
Slimline®
QuickSet™
TAC
Standard
TAC
Quarter-Turn
Tension
Anchor
4.0 inchX
4.5 inchXXXX
5.0 inchXXX
5.5 inchXXXX
7.0 inchXXXX
7.625 inchXXX

Additional tubing anchor sizes are available upon request, including unique or custom-built anchors. For example, TechTAC® has delivered TACs to fit 6- and 6 5/8-inch wells, in addition to oversized tools for 8 5/8- and 9 5/8-inch wells.

More Sizes, More Solutions

Offering its patented Slimline® TAC in a wide variety of common and custom sizes allows operators in all the major plays in North America to take advantage of the product’s unique design and benefits. With a reduced overall diameter compared to a standard B2 TAC, the Slimline® delivers increased flow through the annulus of up to 245%. And the anchor’s tapered design on top and bottom reduces the area for potential debris collection.

This unique design has been shown to:

  • Reduce gas locking incidents by directing gas around the anchor
  • Limit stuck anchors by preventing the accumulation of sediment
  • Dramatically reduce cutover time
  • Increase pump performance and longevity
  • Minimize scale buildup by reducing turbulent flow
Pump jack oil well in field

A senior completion foreman with a U.S.-based oil and gas company describes the benefits of the Slimline® TAC in this way: “Scale builds up where there is a major pressure drop. With a standard TAC there’s not sufficient flow-by area around the TAC. You end up with high pressure below the TAC and low pressure above, so the scaling occurs at the TAC. Slimline anchors reduce this issue by significantly reducing the high/low pressure change above and below the TAC.”

Supported by CFD Analysis

As fluid flows around an anchor, issues like pressure drop, turbulence and changes in velocity can create significant problems, especially with a standard B2 TAC. Among other challenges, those factors can cause the formation of scale, paraffin and iron sulfide. However, a recent computational fluid dynamics (CFD) analysis conducted by Imaginationeering found that the pressure drop around the TechTAC® Slimline® is less than half that of the standard TAC, making it much less susceptible to scaling. Other factors, such as changes in fluid velocity were also less pronounced around the Slimline®.

CFD analysis of two types of TACs

According to the study: “…the pressure drop along the standard TAC is more than double that drop along the Slimline TAC. This is expected because the annular cavity with the Slimline TAC’s case is wider than that for the standard TAC’s case. Furthermore, the pressure drop change in the Slimline TAC’s case is less abrupt than that in the standard TAC’s case in which a noticeable localized drop prior to the downstream connector is observed.”

To learn more about the TechTAC® Slimline®, available sizes or the simplified assembly procedure for the 7 5/8-inch anchor, contact the TechTAC® team today.

Best Practices for Using the TechTAC® Slimline® in Deep or Deviated Wells

Summary: The Slimline® QuickSet™ TAC can be fully set in deep or deviated wells that are hard to reach with traditional tubing anchors. Follow these best practices to maximize the effectiveness of the QuickSet™ anchor.

Tightening the top sub of a Slimline anchor

Anchoring a production tubing string can be especially challenging in deep or deviated wells. The distance and/or bend of the wellbore can make it difficult to get sufficient torque rotations down to the tool to fully set a traditional tubing anchor catcher (TAC). For these situations, TechTAC® created the Slimline® QuickSet™ TAC. The QuickSet™ anchor is designed to give engineers more flexibility when anchoring tubing strings in wellbores with extreme geometry. However, getting optimal value from the patent-pending Slimline® QuickSet™ TAC requires careful attention to some key best practices.

4 Key Considerations When Running a Quick-Setting TAC

  1. Use caution when running the anchor in and out. While this piece of advice sounds obvious, it’s especially important when working with the Slimline® QuickSet™. Because the QuickSet™ anchor can be set and released in 1-to-3 turns, as opposed to the traditional 6-to-8 turns, being cautious and deliberate about how the anchor is run in and out of a well is even more important than with a traditional TAC.
  2. Put a right-hand turn in the tubing occasionally. To prevent the tool from setting while running in, it is advisable to occasionally (about every 5-to-10 stands) put a right-hand turn in the tubing. Doing so will help prevent the anchor from setting prematurely. (If you are running a right-hand set TAC, put a left-hand turn in the tubing.)
  3. Use a pipe wrench instead of power tongs. When adding that right-hand turn every 5-to-10 stands, it’s important to use a pipe wrench instead of power tongs. The pipe wrench will allow you to feel when the tool is fully released and avoid damaging it. If you use power tongs, you could over-release the tool and shear the pipe plug. In turn, the anchor could bind up and fail. If there are times when it isn’t feasible to use a pipe wrench to add the right-hand turn – such as in very deviated or deep wells – the power tongs should be set to slow speed.
  4. Slow down. Especially when going through a tight spot in the well or when hitting fluid, it’s essential to take a slow, deliberate approach to running, placing, and setting the anchor.

A Powerful Combination for Deep or Deviated Wells

The Slimline® QuickSet™ TAC offers a flexible solution for anchoring production tubing strings in deep or deviated wells. Compared to the original Slimline® or a standard TAC, the QuickSet™ requires fewer string rotations to fully set the anchor. Yet it retains the patented Slimline® design, which increases flow-by capacity in the annulus by as much as 245%. That combination has helped the Slimline® QuickSet™ TAC support a wide range of deployments.

Inspecting a Slimline anchor

One engineer with a large energy company operating in the Permian described the anchor’s impact this way: “Despite trying a variety of different products, we could not get a tubing anchor to set in the dogleg of one of our horizontal wells. We tried standard and quarter-turn anchors but kept getting the same result. Finally, after hearing about the Slimline QuickSet TAC, we decided to give it a try – and we were able to fully set the anchor in the bend of the well.”

For more information about the Slimline® QuickSet™ TAC, download the product brochure or visit the QuickSet™ product page.

New CFD Study Shows the Impact of Pressure Drop Around Different Types of Tubing Anchor Catchers

An abrupt drop in pressure within the annular space around a TAC can lead to significant challenges like gas locking in rod pumps and the formation of scale

SALT LAKE CITY – Jan. 9, 2023 – A new computational fluid dynamics (CFD) study from the independent consulting firm Imaginationeering finds that the net pressure drop around a standard Baker B2-style tubing anchor, as fluid/gas passes through the annular cavity around the anchor, is more than double the pressure drop around TechTAC’s Slimline® Tubing Anchor Catcher (TAC). A significant pressure drop, like that around the standard anchor, is the primary issue causing gas locking in rod pumps and a major contributor in the formation of scale, iron sulfide, and paraffin.

CFD comparison of two tubing anchor catchers
The CFD study found a much more significant pressure drop when fluid/gas passes around the standard anchor as compared to the TechTAC® Slimline® anchor.

The CFD study was commissioned by TechTAC® and provides “a comparison CFD analysis of a gas flow within the annular space around two types of a 5.5-inch tubing anchor catcher to assess the differences between them in terms of flow parameters.” The two TACs used in the comparison were a standard tubing anchor catcher and the Slimline® TAC.

According to the study: “…the pressure drop along the standard TAC is more than double that drop along the Slimline TAC. This is expected because the annular cavity with the Slimline TAC’s case is wider than that for the standard TAC’s case.” The Slimline® anchor also demonstrated a noticeable advantage over the standard TAC in reducing the overall turbulence and vorticity strengths within the flow field.

“Standard tubing anchors can restrict annular flow in a well casing, which may lead to issues that can greatly reduce production,” said Bruce Friesen, president of Friesen Oil and Gas Consulting and former global artificial lift advisor with BP. “However, as this new CFD study demonstrates, the geometry of the Slimline® TAC provides a noticeable advantage over the design of the standard TAC by providing more consistent fluid velocity and vorticity, and minimizing pressure drops and turbulent flow.

“With those factors in mind, it’s likely that the installation of a Slimline® TAC versus a standard TAC can – over time – reduce workover costs, increase production rates, and provide for optimized completion designs,” Friesen said.

A summary of the CFD report is available at no cost at https://go.techtacco.com/techtac-cfd-report-download.

About TechTAC®

Established in 2004, TechTAC® is an oil industry solution provider built on three guiding principles: quality that performs, service that exceeds expectations, and respect for our industry family of workers and customers. TechTAC® designed and developed the patented Slimline® Tubing Anchor Catcher (TAC) to help reduce oil well downtime and maximize the life and efficiency of pumps and other production equipment. TechTAC® products are sourced and manufactured exclusively in the United States and are available through a network of Authorized Dealers – including local pump shops and service companies – throughout North America. For more information, visit www.techtacco.com.

Media Contact:
Shawn Dickerson
TechTAC® Marketing Director
[email protected]

Potential Use Cases for AI in the Oil and Gas Industry

Summary: The oil and gas industry is often at the forefront of technology adoption to improve operational efficiency. The next wave of technological advancement appears to be AI, which offers several promising use cases for the oil patch. Areas like demand forecasting, corrosion detection, and safety could be greatly enhanced using AI.

AI applications in the oil and gas industry

The technology of the moment is certainly artificial intelligence, or AI. Stories about its uses and potential applications are everywhere – and the oil industry is no different. Following is a roundup of some of the latest perspectives on how AI will impact the oil and gas industry:

Improving Demand Forecasting

In a recent post, software firm Appinventiv highlighted many promising use cases for AI in the oil patch. One of the key applications cited in the article is demand forecasting:

“Traditional methods of demand prediction often fall short in handling the complexities of today’s global energy markets. This is where AI solutions for oil and gas, powered by advanced machine learning algorithms, are revolutionizing demand forecasting processes.

“AI models can uncover intricate patterns and correlations that human analysts might miss by analyzing vast amounts of historical data, market trends, geopolitical events, and even social media sentiment. This empowers companies to make well-informed decisions based on data-driven insights.”

Automating Corrosion Detection

Corroded pipeline

A related post from consulting firm V-Soft Consulting noted the potential applications of AI to reduce production and maintenance costs. The article describes one approach to automating corrosion detection:

“Oil or gas extracted using oil rigs is stored in a central repository and then distributed across pipelines. Due to various temperatures and environmental conditions, oil and gas components often face material degradation and corrosion. Corrosion can cause component deformation, which results in faded threading or can weaken the pipeline itself. Not handling this problem can result in catastrophic damages halting the entire production process. This is one of the biggest concerns of the industry and companies employ corrosion engineers to monitor and handle the health of components to avoid corrosion activities….

“AI solutions can prevent incidents like this from occurring. AI and [internet of things] technologies can detect signs of corrosion by analyzing various parameters using knowledge graphs and predictive intelligence to approximate the corrosion occurrence probability and raise alerts to pipeline operators. This way companies can be proactive in handling the corrosion risks and moreover, based on knowledge graph analysis, study various machinery downtimes and predict time to carry out maintenance activity. This way, companies plan and adjust for downtime.”

Enhancing Workplace Safety

Workplace safety equipment

Finally, Acuvate, another digital consulting and services firm, describes how AI could drive greater workplace safety:

“Powerful technologies like AI … monitor on-field operations to identify fatal signs, such as hazardous gas levels and unauthorized personnel access.

“AI-enabled chatbots then issue real-time alerts on mobiles and smart wearable devices, such as health or lockout emergency notifications, permitting them to work on-field, thus creating a more connected on-field workforce.

“Additionally, smart watches, safety helmets, biometric vests, and Bluetooth tags monitor workforce activities, track field operator locations, identify signs of workforce fatigue, and enable access to critical information on the field.

“…AI can detect and troubleshoot on-site hazards in real-time or send notifications to dispatch experts as and when required.”

AI in the Oil and Gas Industry

The adoption of AI is also cited as a key trend in Deloitte’s 2024 Oil and Gas Industry Outlook. The report states:

“The O&G industry has often been at the forefront of adopting cutting-edge technologies to bolster operational efficiency, curtail costs, and advance safety and sustainability measures. In recent years, artificial intelligence has emerged as a transformative force for the industry, with applications across the O&G value chain, from initial resource exploration to the intricacies of refining processes. Among applications, AI-driven predictive maintenance is instrumental in achieving a multitude of objectives, including cost reduction, heightened productivity, and the assurance of operational reliability for the industry.”

The Deloitte study goes on to highlight four key dimensions that outline the potential value of generative AI – a branch of AI that creates new content, such as images or text – as described in the figure below:

Deloitte graphic highlighting generative AI in the oil and gas industry

In the years to come, as efficiency, safety, and sustainability become ever-more important to the success of oil and gas companies, it’s likely that AI technologies will be an increasingly vital part of that transformation.

What Does the Slimline® TAC’s Increased Flow-by Area Actually Look Like?

Summary: See a visual comparison of the flow-by area of the 5.5” Slimline® TAC when compared to a similarly sized Baker B2-style (standard) anchor. That increased flow-by capacity helps mitigate the risk of traditional downhole challenges like gas locking, pressure drops, and sediment buildup.

A 5.5" Slimline® anchor in casing

Sometimes benefits are a little tough to visualize. If you’re in the market for a new truck, it’s one thing to read about a vehicle with a 40,000-pound towing capacity. It’s something quite different to see that truck hauling 20 tons of rock and steel up a grade on the way to a jobsite. More often than not, seeing is believing.

A Flow-by Area Comparison

In the case of the Slimline® Tubing Anchor Catcher (TAC), documenting the increased annular area around the TAC, when compared to a Baker B2-style (standard) anchor, isn’t as compelling as seeing it in action. The Slimline® offers an increased flow-by capacity of up to 245%. That distinction can best be seen in a side-by-side comparison:

The Slimline® (left) provides significantly more annular flow-by area than the standard anchor (right).

Both photos feature a 5.5” TAC within 17 ppf casing. The Slimline® on the left shows a much wider annular area. That increased flow-by area is what allows the Slimline® to reduce the occurrence of gas locking in sucker rod pump systems, as well as limit the number of stuck anchors. Gas can more easily flow up and around the Slimline®, while sand and sediment can fall past the anchor without cementing it in place.

One engineer with a large production company operating in the Southern United States described it this way: “Sand was a frequent problem in many of our wells. It would fall on top of a standard TAC and cement the anchor in place. After switching to the Slimline, that problem all but disappeared.”

A Closer Look

These next photos make the difference clearer with the addition of a tape measure. The 5.5” Slimline® offers a flow-by OD of 3.75 inches, compared to 4.50 inches with the standard TAC. In addition to minimizing downhole problems with gas and sand, that increased flow-by capacity minimizes the pressure drops and turbulent flow that precipitate out scale, iron sulfide, and paraffin.

The tape measure highlights the difference in flow-by area between the Slimline® (left) and the standard anchor (right).

Through almost 20 years of experience, we’ve found very few instances where a Slimline® TAC couldn’t benefit most downhole production strings. However, we offer a range of downhole tubing anchor solutions to be compatible with your downhole assembly, including standard (Baker B2 style) and quarter-turn anchors, as well as the patented Slimline® and Slimline® QuickSet™. For more information about any of these solutions, contact the TechTAC® team today.

Original Manufacturer vs. Aftermarket Parts: Which are Best for Your Downhole Equipment?

Summary: When it comes to oil field components, authenticity matters. Choosing genuine replacement parts from an original manufacturer instead of aftermarket components helps ensure the proper operation of downhole equipment. Using original manufacturer replacement parts that are made in the USA guarantees those parts meet the engineering specifications and tolerances required for proper fit, component integrity, and top-notch performance and reliability. For TechTAC® tubing anchor catchers, trust in genuine TechTAC® replacement parts.

Precision parts from TechTAC®
Genuine TechTAC® replacement parts are manufactured in the United States. They use the same high-grade steel and precision machining processes as the original products.

When it’s time to repair or rebuild a piece of downhole equipment, one of the main questions an operator needs to answer is whether to use parts made by the original manufacturer or aftermarket parts made by a third-party supplier. Both options have certain advantages. The right choice depends on an operator’s business and production goals.

This article will outline five important factors to consider when evaluating replacement parts. Specifically, we’ll look at:

  • Quality and steel grade
  • Short- and long-term costs
  • Compatibility and fit
  • Availability and customer service
  • Lifespan and component integrity

Quality and Steel Grade in Original Manufacturer Parts vs. Aftermarket

Perhaps the most significant difference between original manufacturer and aftermarket parts is the assurance of quality. That’s not to say aftermarket parts will necessarily be poor quality. Rather, there’s no guarantee of quality with an aftermarket component.

In contrast, the original manufacturer can control the quality of every component and replacement part. The manufacturer has oversight into not just the workmanship employed in manufacturing a part but also the materials used to create it.

Steel frame with threaded hole
Using replacement parts made of high-grade U.S. steel helps ensure toughness, durability, and corrosion resistance.

Combining a product made from high-grade U.S. steel with an aftermarket replacement part of questionable origin increases the risk of system failure. Without the assurance of quality from the original manufacturer, aftermarket replacement parts may not have the correct metallurgy to provide yield and tensile strength, toughness, durability, corrosion resistance, and adequate tolerances. For example, certain dissimilar metals will cause electrolysis where one metal begins to lose its mass due to corrosion, thereby weakening it. And it’s not necessarily the inferior part that loses material. That process can affect the higher-grade steel as well. 

These issues could be especially dangerous when dealing with a tubing anchor catcher (TAC). The main purpose of the TAC is to keep the tubing string in constant high-load tension – upwards of 40,000 lbs. All the components of the anchor – the slips, the body, and the internal parts – need to resist the cyclic loading of the tubing as the rod pump reduces the hydrostatic load on the anchor on the upstroke and then transfers that load back to the anchor on the downstroke. That’s over 11,500 cycles in one day at 8 strokes per minute (spm).

When a piece of equipment is at 7,000 to 14,000 feet under constant high stress, every component must be top-notch.

Short- and Long-term Costs

Another important factor in evaluating original manufacturer versus aftermarket parts is cost. While there are some exceptions, in general, aftermarket parts are less expensive than those made by the original manufacturer. If short-term cost containment is a company’s top priority, aftermarket parts may be a good option.

However, the lower price may also increase certain risks. If the low price comes at the expense of quality, it could lead to a product failure. And that failure will cost far more than the initial savings on aftermarket parts. For example, saving a few hundred dollars on lower-quality aftermarket parts certainly doesn’t offset the increased risk of a costly downhole fishing job. In such a scenario, a workover rig will likely cost more than $10,000 per day.

Workover rig engaged in a well repair
Downhole equipment failures resulting from poor-quality replacement parts can be extremely expensive. A workover rig for a fishing job can cost in excess of $10,000 per day.

In some ways, evaluating the cost difference between original manufacturer and aftermarket parts hearkens back to an old TV commercial for FRAM oil filters. In it, an auto mechanic and an engine repair specialist talk about using high-quality parts to maintain engine performance versus paying for an expensive engine rebuild later. The commercial aptly ends with the line, “You can pay me now, or you can pay me later.” When it comes to auto engines or downhole equipment, paying now for high-quality parts is always a better investment than paying later for expensive repairs and lost productivity.

Compatibility and Fit

Not all parts are created equal, even if they’re made from the same materials using similar machining processes. Different companies make parts in slightly different ways. Using aftermarket replacement parts creates a risk that connections and threads won’t match. They could also compromise the effective operation of a tool. If the thread pitch is not exactly matching, for example, issues with the galling, make up, and tensile strength of a connection could arise.

Once again using the example of a TAC, compatibility goes beyond the quality of the components. The different parts of the anchor must be timed so that various mechanical elements meet in a specific way. For instance, with the Slimline® TAC, the body nut includes a steel nipple pointing down. The upper cone features a similar nipple pointing up. Those two nipples must contact at precisely the right place to ensure effective operation of the anchor. If one of those parts reaches the end of its threads before those nipples contact, the anchor could bind together and compromise the setting process. Using genuine TechTAC® parts in every anchor ensures the necessary level of interchangeability.

As one manager at an oilfield supply company in Texas commented, “We used to buy tubing anchors from a variety of manufacturers, but we often encountered problems, like oversized components, with other companies. Today we buy exclusively from TechTAC….”

Engineering resources from TechTAC®

Availability and Customer Service

In general, aftermarket parts for downhole equipment are more widely available than original manufacturer parts. Original manufacturer parts are typically available through a single company, while aftermarket parts can be produced by many suppliers. However, an abundant supply of a given part isn’t the only factor in determining availability. Delivery timelines can also have a significant impact. A widely available aftermarket part may be locked into a slow fulfillment process if the part is not a core competency of the aftermarket manufacturer.

Palettes of TechTAC® Slimline® anchors
The availability of downhole products and replacement parts is determined not just by the number of suppliers offering a product, but also those suppliers’ delivery timelines. Most TechTAC® anchors and replacement parts are delivered or shipped within 24 hours.

Another factor in the availability of repair parts is whether an operator knows where to turn if there’s an issue. Consider this example:

Several years ago, as the TechTAC® Slimline® anchor was becoming a standard in the downhole completion designs of many operators, some engineers were starting to ask for the product by name. One enterprising manufacturer wanted to capture those requests by creating a Slimline® copycat anchor. However, the copycat used inferior components, except for one piece, which they purchased directly from TechTAC®. It was sort of like buying a Toyota truck but putting a Chevy tailgate on the back.

The copycat anchor struggled to perform under pressure. When the operators removed the broken anchors and saw the TechTAC® name, they assumed it was a TechTAC® product. Only after shipping the anchors to TechTAC® headquarters did the team discover that most of the parts came from another manufacturer.

The whole process cost the operator several days of production. Delays that could have been avoided through the use of genuine TechTAC® parts.

Lifespan and Component Integrity

The lifespan of downhole equipment parts is largely determined by the overall quality of the production process and the integrity of the resulting components. The higher the quality of the part, the longer an operator can stay productive after a replacement or rebuild.

With TechTAC® tubing anchors, using genuine TechTAC® parts is the best way ensure the quality and integrity of replacement components. The most reliable parts will leverage the same high-grade U.S. steel, the exact matching thread specifications, and proper sizing. In turn, the lifespan of those parts is maximized, even when under enormous pressure.

The Value of Original Manufacturer Parts

Replacing worn or damaged parts can be an excellent way to extend the life of downhole equipment. When choosing where to purchase those parts, buying from the original manufacturer offers many advantages. While genuine manufacturer parts may carry a slightly higher price tag, they tend to be higher quality, more compatible, and longer lasting.

TechTAC® offers a catalogue of replacement parts for all its tubing anchor catchers, including both the Slimeline® TAC and standard TACs. Those parts are manufactured in the United States, using the same high-grade steel and precision machining processes as the original products. That commitment gives operators and service providers confidence in the quality, compatibility, and lifespan of every part they purchase.

CFD study graphic

Statistics Highlighting the Economic Benefits of the American Oil and Gas Industry

Summary: The oil and gas industry is a major contributor to the health of the American economy and various state economies around the nation. The statistics below, collected from various sources, highlight the positive impact of oil and gas production.

Oil pumpjack in Midland, Texas
  • Oil, natural gas, and coal provide 80% of American energy (source: U.S. Department of Energy).
  • Every year, an American family of four saves around $2,500 as a direct result of oil and gas accessibility (source: Pro-Gas Services, LLC).
  • In 2021, the U.S. oil and gas industry supported 10.8 million total jobs or 5.4% of total U.S. employment (source: American Petroleum Institute).
  • It generated an additional 3.7 jobs elsewhere in the U.S. economy for each direct job in the natural gas and oil industry (source: American Petroleum Institute).
  • The oil and gas industry produced $909 billion in labor income, or 6.4% of the U.S. national labor income (source: American Petroleum Institute).
  • It supported nearly $1.8 trillion in U.S. gross domestic product, accounting for 7.6% of the national total (source: American Petroleum Institute).
  • Fiscal Year 2022 was a record-breaking, blockbuster year for the Texas oil and natural gas industry, which contributed $24.7 billion in state and local taxes and state royalties (source: Texas Oil and Gas Association).
  • The revenue from Texas oil and natural gas production, pipelines, refineries and LNG facilities translates into about $67 million each day that pay for the state’s schools, universities, roads, first responders and essential services (source: Texas Oil and Gas Association).
  • Texas: The oil and gas industry generates $454.5 billion for the state’s economy (source: American Petroleum Institute).
  • California: Generates $217.1 billion for the state’s economy (source: American Petroleum Institute).
  • Pennsylvania: Generates $75.0 billion for the state’s economy (source: American Petroleum Institute).
  • New York: Generates $70.1 billion for the state’s economy (source: American Petroleum Institute).
  • Oklahoma: Generates $57.5 billion for the state’s economy (source: American Petroleum Institute).
  • Ohio: Generates $55.5 billion for the state’s economy (source: American Petroleum Institute).
  • Illinois: Generates $55.3 billion for the state’s economy (source: American Petroleum Institute).
  • Louisiana: Generates $54.3 billion for the state’s economy (source: American Petroleum Institute).
  • Florida: Generates $53.1 billion for the state’s economy (source: American Petroleum Institute).
  • Colorado: Generates $48.7 billion for the state’s economy (source: American Petroleum Institute).
  • The U.S. trade deficit in 2019 was $305 billion lower than it would have been without domestic oil and natural gas production (source: U.S. Department of Energy).
  • Oil and gas contributions made up roughly 35% of New Mexico’s state budget in 2021, clocking in at a total of $2.9 billion (source: NTG Environmental).
  • In New Mexico, oil and gas contributed over $1.4 billion to public education. Roughly $991 million went toward K-12 education and about $262 million contributed toward higher education (source: NTG Environmental).
  • By 2040, [“tight” rock formations like shale] and other technology-driven sources of oil and gas are expected to meet about one-fifth of the world’s energy needs (source: XTO Energy).
  • Between 2012 and 2025, the oil and gas industry is projected to provide $1.6 trillion in federal and state tax revenue, supporting the maintenance of schools, hospitals, and public infrastructure across the country (source: U.S. Department of Energy).
  • Texas: The oil and gas industry directly supports 508,000 jobs (source: PwC Economic Impact Report).
  • California: Directly supports 160,000 jobs (source: PwC Economic Impact Report).
  • Oklahoma: Directly supports 101,000 jobs (source: PwC Economic Impact Report).
  • Pennsylvania: Directly supports 93,000 jobs (source: PwC Economic Impact Report).
  • Louisiana: Directly supports 92,000 jobs (source: PwC Economic Impact Report).
  • Ohio: Directly supports 71,000 jobs (source: PwC Economic Impact Report).

By supporting millions of jobs and providing billions of dollars in tax revenue for essential public services, the American oil and gas industry is a vital part of the U.S. economy. TechTAC® – maker of the patented Slimline® Tubing Anchor Catcher – is proud to be part of this important industry.

Engineering resources from TechTAC

TechTAC® Highlights Tubing Anchor that Can Navigate Oil Well Casing Patches

SALT LAKE CITY – Nov. 7, 2023 – TechTAC®, an industry leader in downhole tubing anchor solutions, today highlighted the availability of the Slimline® Casing Patch TAC, a tubing anchor catcher that gives engineers and field personnel more options for anchoring a tubing string within an oil well where the wellbore casing has been patched, is swollen or has a reduced ID due to scale. This custom-made anchor leverages innovative mechanics and the unique design of the Slimline® to navigate an oil well casing patch or similar anomaly while still being able to fully set below the patch or affected area.

A stack of oil well casing segments (photo courtesy of Borregaard)

“Oil well casings may need to be patched for a variety of reasons – from corrosion to mechanical damage – and those patches can create unique challenges for tubing anchors,” said Luke Reary, Operations Manager with TechTAC®. “A TAC that is small enough to pass through a patch sleeve usually isn’t large enough to be securely set in other portions of the well.”

As a workaround, some operators choose to set the anchor above the patch. However, this approach can limit the effectiveness of the anchor if the casing patch is placed high up within the well. For instance, if a casing patch is deployed at 2,000 feet within an 8,000-ft well, setting the TAC above the patch means the anchor is not securing most of the production string, making the tubing much more susceptible to wear and tear and hampering pump efficiency.

The Slimline® Casing Patch TAC gives engineers and field personnel an alternative to this workaround. For example, a 5.5” 20 PPF patched casing has a reduced drift of 4.218” compared to 4.653” for an unpatched casing drift. In that setting, the OD of the Slimline® Casing Patch TAC is 4.10”. Yet despite a reduced OD that allows it to move through a patched portion of the well casing, the anchor can be fully set using the same setting procedure as the original Slimline®. With that flexibility, operators can set the TAC above or below the casing patch, based on each well’s ideal design.

The Slimline® Casing Patch TAC is available in a variety of sizes based on the unique requirements of each patched well. To learn more or get a quote, contact the TechTAC® team at www.techtacco.com/contact or +1 (435) 781-1675.

About TechTAC®

Established in 2004, TechTAC® is an industry leader in downhole tubing anchor solutions and is founded on three guiding principles: quality that performs, service that exceeds expectations, and respect for our industry family of workers and customers. Relying on decades of experience, TechTAC® designed and developed the patented Slimline® Tubing Anchor Catcher (TAC) to help reduce oil well downtime and maximize the life and efficiency of pumps and other production equipment. TechTAC® products are sourced and manufactured exclusively in the United States and are available through a network of Authorized Dealers throughout North America. For more information, visit www.techtacco.com.

Media Contact:
Shawn Dickerson
TechTAC Marketing Director
[email protected]

Study: Standard Tubing Anchors Can Restrict Production Rates and Pump Fillage

Replacing the AC system in your home is a little like a prostate exam. As the equipment gets older, it’s going to be necessary, but it’s never fun. Such was the case for our family two summers ago when our AC unit finally gave out. Interestingly, one of the main factors contributing to the failure was also a necessary part of the system. The air filter that was needed to keep the circulating air clean was also restricting the airflow too much for the old system to handle. The result was a frequently frozen AC condenser and soaring temperatures in the house.

Oil well rod pump in a snowy field

A very similar issue – where an essential part of the system causes unintended consequences – can occur with standard tubing anchors in oil wells. Tubing anchors are often an important part of the downhole production string. In wells using rod pump systems, the anchors can stabilize the string. That stability prevents unnecessary cyclic movement of the tubing that can cause tubing failure and reduced rod pump efficiency and life. However, that same standard anchor can create serious problems with well production.

The Impact of Tubing Anchors Above the Pump Intake

That was the finding of a research study conducted by Echometer Company. The Texas-based software firm offers solutions for analyzing and optimizing the performance of oil, gas, and water wells. In this case, the firm studied the production rates of 11 oil wells. Each well had high fluid levels and the pump intake was located below the perforations. Yet despite these seemingly favorable conditions, nine of the wells showed a pump fillage rate of less than 90%.

According to the report: “In these wells that exhibited high fluid levels … the fluid distribution in the wellbore below the liquid level was not uniform. The wellbore in the vicinity of the pump intake was primarily filled with gas with a minimal volume of liquid. …The presence of a tubing anchor set high above the pump intake is considered to be the main cause of this uneven distribution of fluids in the wellbore.

“The particular tubing anchor used in these wells provides a flow area of about 2.9 square inches between the body of the anchor and the casing compared to a flow area of 14.4 square inches between the casing (4.892-inch ID) and the tubing (2.375-inch OD). The small flow area could increase the velocity of the upwards flowing gas to the point where it would be difficult for liquid present in the upper part of the annulus to flow downwards past the depth where the tubing anchor is set. The anchor would essentially act as a choke and also cause an increase of the annular back pressure.”

In other words, the tubing anchor itself was restricting the flow of gas up through the annulus of the well. The gas that did escape had an increased velocity. That velocity made it difficult for fluid above the anchor to fall past it and reach the pump. In turn, the fluid around the pump had a high gas content, making highly efficient production impossible.

Tubing Anchors Can Provide a ‘False Positive’

Another key finding in the report was related to the fluid levels in these wells. In many cases, the fluid levels above the anchors appeared higher than they actually were. The report states: “Fluid level depression tests were used to confirm that free gas can collect below a tubing anchor and prevent the liquid present in the gaseous column above the tubing anchor from falling to the bottom of the wellbore and to the pump intake.”

Said differently, the fluid above the anchor was unable to fall past the anchor at a significant enough rate to allow full pump fillage and decrease the overall fluid level. This phenomenon essentially gave operators a false reading, since they thought they had high fluid levels. However, the reality was that fluid just couldn’t get past the anchor as quickly as it was being pumped out.

Possible Solutions

The Echometer team notes that removing the anchor or moving it below the perforations should resolve the issue. Of course, neither option is necessarily ideal. Removing the anchor would increase the flow area within the casing. However, it would also cause the cyclic movement of the tubing string. And although setting the anchor below the perforations can be an effective model with the right equipment, many engineers and field operators are wary of this approach.

Consider the Slimline® Tubing Anchor Catcher from TechTAC®

Thankfully there is another possible solution. The design of the patented Slimline® Tubing Anchor Catcher improves the flow-by capacity of fluid in the annulus by as much as 245% over a standard anchor. That increased flow-by area allows gas to more easily flow up the well, rather than being trapped around the pump. The Slimline® also features tapered flow deflectors on the top and bottom. That tapered design, along with the anchor’s reduced OD, virtually eliminates the risk of sediment or paraffin building up on top of the anchor. As such, it can be safely set above, in, or below the perforations, depending on the well design.

Assembling a TechTAC® Slimline® anchor

One U.S.-based oil and gas company saw these benefits firsthand. “We were having trouble with high fluid levels because the fluid could not sufficiently drop past a standard anchor,” said a senior completion foreman with the company. “Those elevated levels were causing some pump failure due to gas locking. We tried the Slimline TAC, and in every well we tested, fluid levels were at or just above the anchor.”

Conclusion

A tubing anchor is an important element of many downhole production strings. However, the study by Echometer found that those same standard anchors can restrict production rates and pump fillage. The Slimline® Tubing Anchor Catcher from TechTAC® provides an alternative to standard anchors. The Slimline’s increased flow-by capacity can reduce or eliminate many of the issues identified in Echometer’s research.

To access the complete Echometer study, titled Tubing Anchors Can Reduce Production Rates and Pump Fillage, visit the Society of Petroleum Engineers’ research website www.onepetro.org. For more information about TechTAC’s downhole tubing anchor solutions, including the Slimline® TAC, visit the company’s anchor product pages.

Engineering resources from TechTAC

Products Made from Oil and Natural Gas

For most Americans, a phrase like “the oil and gas industry” conjures up images of fuel pumps and gas furnaces.

While transportation and heating are perhaps the most recognizable uses of oil and natural gas, the applications for petrochemicals derived from these sources is actually much, much broader. The infographic below from the U.S. Department of Energy highlights a list of more than 160 common everyday products made from derivatives of oil and natural gas. Some potentially surprising items on the list include:

  • Antihistamines (allergy medications)
  • Bandages
  • Candies and gum
  • Denture adhesives
  • Hair coloring
  • Insulation
  • Nail polish
  • Perfumes
  • Rubbing alcohol
  • Spacesuits
  • Toothpaste
  • Yarn

Download a PDF version of the full infographic at the U.S. Department of Energy website.

Anchoring a Production String After an Oil Well Casing Patch Has Been Applied

Oil wells are a crucial component of the global energy infrastructure. To ensure the safe and efficient extraction of oil, oil well casings play a pivotal role in maintaining well integrity. However, over time, these casings may develop issues that require attention to prevent environmental contamination and ensure the longevity of the well. Specifically, an oil well casing patch may need to be applied. In this article, we will explore the reasons an oil well casing might require a patch, the methods involved in patching it, and how operators can properly anchor a production string within a patched well.

Oil drilling rig

Reasons for Applying an Oil Well Casing Patch

The need for an oil well casing patch can arise from any number of issues. Some of the most common factors include:

  • Corrosion: Corrosion is one of the most common problems affecting oil well casings. Over time, exposure to harsh underground environments, containing corrosive elements such as brine, hydrogen sulfide, and carbon dioxide, can lead to the deterioration of casing materials. This corrosion can create holes or weaken the casing’s structural integrity, risking oil and gas leakage into surrounding groundwater.
  • Mechanical Damage: Mechanical damage can occur during the drilling and completion process or because of external factors. This damage can manifest as cracks, dents, or fractures in the casing, jeopardizing the well’s containment capabilities.
  • Aging: Oil well casings have a finite lifespan. As they age, they become susceptible to fatigue, stress, and material degradation. This natural aging process can result in the need for patching to maintain well integrity.
  • Cement Bond Failure: Sometimes the cement used to seal the casing to the wellbore fails to provide adequate isolation. This can allow fluids to migrate between different geological layers, potentially leading to contamination or pressure imbalances.
CFD study graphic

Methods for Applying an Oil Well Casing Patch

A number of methods are available to patch the casing of an oil well, depending on the severity and type of issue. These include:

  • Perforation Sealing: One common method for patching oil well casings involves sealing perforations or holes in the casing. Rig crews can apply this patch using various materials, including cement, epoxy resins or specialized metal patches. The choice of material depends on the size and location of the perforation.
  • Casing Repair Sleeves: Casing repair sleeves are cylindrical devices that cover damaged sections of the casing. Rig crews deploy these sleeves by sliding them over the damaged area and securing them in place with mechanical fasteners. This method is particularly effective for addressing cracks and fractures in the casing.
  • Resin Injection: For smaller cracks or voids in the casing, resin injection is a viable option. The rig crew injects a specialized resin into the damaged area, where it hardens and forms a seal. This method is effective for repairing minor defects and is relatively quick and cost-effective.
  • Sectional Casing Replacement: In situations where the damage to the casing is extensive, it may be necessary to replace entire sections of the casing. This involves removing the damaged section and installing a new one in its place. Sectional casing replacement is a more complex and costly process but may be required in some extreme scenarios.
  • Cement Squeeze: Pumping a specialized blend of cement under pressure into the casing breach is the most economical and common method for restoring casing integrity. This method is usually not applicable if the casing must support high pressure operations, such as a fracture stimulation job, in the future. A casing sleeve would be a more likely solution in those circumstances.

Unique Challenges for Tubing Anchors

An oil well casing patch often presents unique challenges when operators try to set tubing anchors catchers (TACs) within the patched well. A TAC that is small enough to pass through the patch sleeve usually isn’t large enough to be securely set in other portions of the well. As a workaround, many operators choose to set the anchor above the patch. This method can be effective if the casing patch is at 7,000 feet in an 8,000-ft well. But if that same patch is sitting at 2,000 feet, the TAC isn’t securing most of the production string, making the tubing much more susceptible to wear and tear and hampering pump efficiency.

A Slimline® TAC for Patched Oil Wells

Slimline TAC components

TechTAC® offers the Slimline® Casing Patch TAC to address the difficulty associated with anchoring a tubing string within a patched oil well. This custom-made anchor leverages innovative mechanics and the unique design of the Slimline® to navigate an oil well casing patch while still being able to fully set below the patch.

The Slimline® Casing Patch TAC can be custom made to fit the unique requirements of virtually any patched well. To learn more or get a quote, contact the TechTAC team.

Engineering resources from TechTAC

The Benefits of Using a Tubing Anchor with a Rod Pump System

A tubing anchor plays an important role in safe and efficient production operations. Not only does it provide stability to the tubing string, it also prevents unwanted vertical and lateral movement. This is particularly the case in highly deviated and high productivity wells.

Oil worker using a hydraulic wrench

In wells that utilize rod pump systems, the use of tubing anchors can provide several advantages. These advantages contribute to increased production efficiency, lower operating expense (OPEX) and higher safety. Some key benefits include:

  • Higher pump efficiency – By stabilizing the tubing string, a tubing anchor can improve the efficiency of the rod pump system. In wellbores with tubing that is freely suspended, tubing has a tendency to elongate on the pump down stroke. At the same time, the rods contract (i.e., shorten). Conversely, on the up stroke, the tubing contracts and the rods elongate. This effectively reduces travel distance, which in turn, decreases production. A tubing anchor prevents such a condition from occurring.
  • Minimizes wear on rods, tubing, casing and the pump – The continuous cycle of elongating and contracting increases the risk of tubing buckling. In such cases, the tubing string can bend and/or coil, causing it to rub against the rod and/or the casing. This motion causes wear to the casing, the tubing and the pump barrel. In turn, the risk of early failure is heightened, as is the potential need for costly interventions. The added friction also necessitates more power for lifting, which increases OPEX. In the case of deep, highly productive wells, if the wear is excessive, the tubing can part and cause an expensive fishing job.
  • Maintains downhole alignment – Tubing anchors help maintain the alignment of the tubing string within the wellbore. Proper alignment is crucial for the efficient operation of the rod pump system. Misalignment can lead to pump component damage and poor pump performance.
  • Reduces vibrations and tubing whipping – A well-designed tubing anchor can help dampen vibrations and reduce tubing whipping, which can occur during pump operation. This is important for safety reasons and to prevent damage to the tubing and other downhole equipment.

Additional Benefits with the TechTAC® Slimline®

While most tubing anchors can deliver the benefits listed above, the unique design of the Slimline® TAC provides additional advantages. In particular, it can help reduce the occurrence of gas locking.

In wells with high gas-to-liquid ratios, gas tends to migrate along the annulus between the tubing and the casing. Standard tubing anchors can create a seal or barrier that causes restrictive turbulent flow, thereby increasing the risk of gas entering the rod pump. When a pump gas locks, the hydrostatic pressure of the column of fluid and gas above the traveling valve of the plunger is greater than the compressed pressure of the gas below the plunger in the barrel of the pump. The end result is little or no fluid entering the tubing, and potentially, a complete halt in fluids production.

With the increased flow area between the anchor outside diameter (OD) and the casing ID (up to 244% increase over the standard anchor), TechTAC’s Slimline® Tubing Anchor Catcher allows gas to flow freely up the casing/tubing annulus rather than through the sucker-rod pump. With its tapered design and smaller diameter, a laminar flowpath is created, reducing the risk of gas interference.

Conclusion

In summary, using a tubing anchor in conjunction with a rod pump system is highly advantageous. It contributes to greater pump efficiency and prevents excessive wear on the tubing, casing and other critical downhole components.

For more information on TechTAC’s line of tubing anchors – which include standard TACs, quarter-turn anchors and the patented Slimline® – visit the anchors product page on TechTAC’s website.

Latest TechTAC® Innovation Gives Operators New Flexibility in Deploying the Patented Slimline® Tubing Anchor Catcher

SALT LAKE CITY – Oct. 3, 2023 – TechTAC®, the manufacturer of the original Slimline® Tubing Anchor Catcher (TAC), today announced the availability of the patent-pending Slimline® QuickSet™ TAC, which can enhance the performance and design of downhole production strings. The new product gives engineers and field personnel more flexibility when anchoring tubing strings deep; in the curve of a horizontal well; and in many cases, where the deviation survey indicates high dog-leg severity (DLS) or cork-screwed wellbore geometry. This flexibility is made possible by the reduction in string torque rotations required to fully set the Slimline® QuickSet™ TAC.

Luke Reary, TechTAC

“There are tens of thousands of Slimline anchors in production today,” said Luke Reary, Operations Manager at TechTAC. “The product’s unique design has made it a key component of many downhole solutions that have been shown to reduce downtime, improve pump performance and longevity, and reduce costly workovers. The new Slimline QuickSet TAC provides all the same benefits as the original Slimline anchor but can be set and released in 1-to-3 turns, as opposed to the traditional 6-to-8 turns.”

The patented original Slimline® anchor design has become a standard in the oil industry because of several unique benefits:

  • The decreased diameter and the tapered flow subs of the Slimline® TAC increases the flow-by capacity in the annulus by as much as 244 percent compared to other available TACs. This improvement in flow-by capacity:
    • Reduces the flow regime from turbulent to a more laminar regime, thereby reducing pressure-drop that can precipitate out scale, iron sulfide, paraffin and other sediment that can accumulate on top of the anchor and plant the entire string, preventing it from being retrieved without an expensive workover.
    • Can reduce the occurrence of rod pump gas locking, which is a common and difficult problem to solve. Workover costs and lost production revenue due to gas locking can add up considerably over time, especially in higher gas/oil ratio (GOR) wells.
  • While the Slimline® TAC design significantly reduces the chance of the anchor getting stuck in a well, as with any downhole tool, in worst-case scenarios it may be necessary to cut over a Slimline® anchor.  A conventional TAC can easily take several days to cut over. In contrast, the TechTAC® Slimline® Tubing Anchor Catcher can dramatically reduce that cut over time because only the slip protectors and slips need to be cut. One operator reported being able to cut over a Slimline® TAC in just 20 minutes.

The Slimline® QuickSet™ TAC provides all those same benefits but with the added ability to set the slips with minimal rotations, thereby providing for unique and flexible wellbore geometric setting positions. For existing customers, the Slimline® QuickSet™ TAC requires no new manuals or complicated setting procedures. The new anchor follows the same setting procedure as TechTAC’s original Slimline® TAC but sets fully in 1-to-3 turns, as opposed to 6-to-8 turns for the traditional model.

For more information about TechTAC’s complete line of Slimline® Tubing Anchor Catchers, visit www.techtacco.com or talk with a TechTAC® Authorized Dealer.

About TechTAC®

Established in 2004, TechTAC® is an oil industry solution provider built on three guiding principles: quality that performs, service that exceeds expectations, and respect for our industry family of workers and customers. Relying on decades of experience, TechTAC® designed and developed the patented Slimline® Tubing Anchor Catcher (TAC) to help reduce oil well downtime and maximize the life and efficiency of pumps and other production equipment. TechTAC® products are sourced and manufactured in the United States and are available through a network of Authorized Dealers – including local pump shops and service companies – throughout North America. For more information, visit www.techtacco.com.

Media Contact
Shawn Dickerson
TechTAC Marketing Director
[email protected]

3 Practical Use Cases for a Quick-Setting Tubing Anchor Catcher

In the oil and gas industry, the need for reliable, efficient, and innovative technologies has never been more pressing. Engineers often find themselves grappling with a variety of complex scenarios—from deep wells and high-pressure environments to limited access locations and wells prone to debris or turbulent flow. Each of these unique situations presents its own set of challenges, especially when it comes to setting a tubing anchor catcher (TAC).

Traditionally, the process of setting an anchor involves 6-8 turns. While this method has been effective for standard operations, there are scenarios where this traditional approach falls short. That’s where the concept of a quick-setting tubing anchor—an anchor that requires only 1-3 turns to be fully set—comes into play.

The idea of a quick-setting tubing anchor isn’t just about speeding up a routine task; it’s about optimizing performance in specialized conditions. Petroleum engineers often face situations where the conventional methods are not only inefficient, but potentially risky as well. This article explores distinct use cases, showing why quick-setting anchors are more than beneficial; in some scenarios, they’re essential.

Use Case 1: Quick-Setting Tubing Anchors in Deep Wells

Deep wells present a unique set of challenges when it comes to setting anchors. The depth of the well itself can make it difficult to generate enough torque at the surface to set the anchor securely. Additionally, the longer the tubing string, the more likely it is to experience significant torsional wind-up, making the setting process even more complicated, especially in grades of steel that exhibit reduced torsional rigidity.

A quick-setting tubing anchor that requires only 1-3 turns would be beneficial in these environments. Not only would it reduce the time and effort required to set the anchor, but it would also minimize the surface torque required to do so. This device could significantly enhance the reliability and safety of operations in deep and deviated wells where additional torque is required to overcome drag.

Use Case 2: Wells with Extreme Wellbore Geometry

Certain drilling conditions can cause a borehole to develop high dog-leg severity or take the shape of a corkscrew. Trenchlesspedia defines dog-leg severity as the “measure of the change in direction of a wellbore over a defined length, normally measured in degrees per 100 feet of length. The more severe a dogleg is, the more potential difficulties arise due to the drill string passing through a curved well trajectory.” Similarly, a corkscrew well—one that spirals downward—can also create downhole challenges.

In the case of tubing anchors, extreme wellbore geometry like these examples can make it difficult for the anchor to fully set, particularly if 6-8 turns are required. The directional changes within the well make it difficult to apply the necessary string torque with surface rotations. A quick-setting anchor overcomes this obstacle by reducing the amount of string torque required to fully set the anchor.

Use Case 3: Horizontal Wells

The number of horizontally drilled oil wells in the United States continues to rise. According to the U.S. Energy Information Administration, “In 2021, 81% of U.S. well completions were horizontal or directional, as opposed to 19% of wells that were drilled vertically.” With this change, the need for quick-setting tubing anchors is rising as well. Like the challenges inherent in deep wells, setting a tubing anchor in the bend of a horizontal well can make it difficult to generate enough torque at the surface to set the anchor securely. Setting the TAC in 1-3 turns is much more practical in horizontal wells than the 6-8 turns required by a traditional anchor.

The Slimline® QuickSet™ Tubing Anchor Catcher

To address these and other use cases, TechTAC® introduced the Slimline® QuickSet™ TAC. This quick-setting anchor can enhance the performance and design of many downhole production strings. The Slimline QuickSet TAC provides all the same benefits as the original Slimline – such as increased flow-by capacity – but with the added ability to set the slips in just 1-3 turns.

The concept of a quick-setting anchor offers distinct advantages in a variety of well scenarios. It’s not just about ease; it’s about enhancing safety, efficiency, and reliability. For petroleum engineers tackling challenging well operations, choosing the Slimline QuickSet TAC could be a game-changer.

The Benefits of U.S. Steel vs. Foreign Steel

Steel is the backbone of modern infrastructure. It’s essential for industries ranging from construction and automotive manufacturing to aerospace and infrastructure development. When it comes to sourcing steel, there are two primary options: domestic (U.S.) steel and foreign steel. Each has its advantages and disadvantages, but in recent years, there has been a growing emphasis on the benefits of U.S. steel. In this article, we will explore the advantages of using U.S. steel compared to foreign steel and why supporting domestic steel production can be a strategic choice for U.S. businesses.

Steel bridge under construction

Quality Control and Standards

One of the most significant benefits of U.S. steel is the rigorous quality control standards the products must meet. American steel mills are subject to strict regulations. Compliance with these regulations ensures that the steel they produce meets or exceeds the necessary specifications for various applications. This commitment to quality gives consumers confidence in the consistency and reliability of U.S. steel products.

Without these quality control standards, the finished steel may not meet the demands of major building projects. Such was the case with the Bay Bridge, which connects Oakland to San Francisco and carries about 260,000 vehicles a day on its two decks. Originally opened in 1936, a replacement for the eastern section of the bridge was opened in 2013. Almost immediately after opening, however, numerous problems surfaced with various steel components of the bridge. The issues required major repairs. During state senate hearings about the troubled bridge, testimony indicated many of the issues were the result of using foreign steel.

CFD study graphic

Environmental Standards

U.S. steel producers are held to high environmental standards, which have led to significant reductions in pollution and greenhouse gas emissions over the years. By choosing U.S. steel, consumers and businesses can contribute to a cleaner environment, as domestic steel production often adheres to stricter environmental regulations than some foreign competitors.

According to the American Iron and Steel Institute, “The American steel industry is the cleanest of the leading steel industries in the world. Of the major steel-producing countries, the U.S. has the lowest CO₂ emissions per ton of steel produced. By contrast, [one foreign supplier’s] steel production creates carbon emissions that are nearly twice that of the U.S. per ton of steel produced.”

Shorter Supply Chains

Using U.S. steel can lead to shorter supply chains. That advantage is especially beneficial for industries that require just-in-time manufacturing or need to respond quickly to market demands. Shorter supply chains reduce lead times, transportation costs, and the risk of supply disruptions due to global events, such as trade disputes or natural disasters. They can also have an impact on customer service. Custom products that are sourced and manufactured within the U.S. can usually reach customers more quickly than products that rely on foreign supply chains.

Leveraging U.S. Steel in TechTAC® Products

The advantages of U.S. steel are an important aspect of the overall quality of TechTAC® products, and in particular, the company’s Slimline® Tubing Anchor Catcher. The high standards of American-made components help to give the Slimline® a uniquely powerful design.

TechTAC products use American-made steel

“We used to buy tubing anchors from a variety of manufacturers,” said the manager of one oilfield supply company in Texas. “But we often encountered problems, like oversized components, with other companies. Today we buy exclusively from TechTAC®, because we know they will deliver consistently high quality.”

In addition to that consistent level of quality, oilfield supply companies like this one trust that if problems do occur, the team at TechTAC® will own the issue and do their best to make it right.

A Commitment to Fast Delivery

In addition to product quality, American-made steel also helps the team at TechTAC® deliver exceptional customer service. Thanks in part to shorter supply chains, TechTAC® offers industry-leading product delivery. Most orders will either be shipped or delivered within 24 hours.

Conclusion

While foreign steel can sometimes offer cost advantages, the benefits of using U.S. steel make it a compelling choice for businesses and consumers alike. Supporting the domestic steel industry not only ensures a reliable supply of high-quality steel but also contributes to the overall strength and resilience of the U.S. economy.

Engineering resources from TechTAC

The High Cost and Impact of a Stuck Tubing Anchor Catcher in an Oil Well

Oil drilling is a complex and costly process, with numerous challenges and risks involved. One of the potential problems that can occur during drilling operations is getting a tubing anchor catcher (TAC) stuck in an oil well. This seemingly small issue can have significant financial, environmental and operational consequences. This article will delve into the cost and impact of getting a standard TAC stuck in an oil well.

A workover rig must be used to remove a stuck tubing anchor catcher

Understanding Tubing Anchor Catchers

Before we explore the cost and impact, it’s essential to understand what a tubing anchor catcher is and its role in oil well operations. A tubing anchor catcher, or TAC, anchors and centralizes tubing strings within the wellbore. It prevents the tubing from moving during production or injection operations, ensuring the efficient flow of fluids in and out of the well, as well as increased longevity for the pump and other downhole equipment.

The Cost of a Stuck Tubing Anchor Catcher

A stuck TAC can create costly operational challenges for production companies, including:

  1. Delayed Production: When a tubing anchor catcher becomes stuck in an oil well, it can cause significant delays in production. Operators may need to shut down the well temporarily while making efforts to retrieve or release the stuck equipment. These delays result in lost revenue for the oil company and can add up quickly.
  2. Equipment and Labor Costs: Efforts to retrieve a stuck tubing anchor catcher often require specialized equipment and skilled personnel. Companies may need to rent or purchase expensive tools like fishing tools, slickline units, or even coiled tubing units to perform the necessary operations. Additionally, skilled technicians and engineers must be on-site to oversee and execute the recovery efforts. The cost of this equipment and labor can be substantial.
  3. Increased Operational Expenses: The longer a well is out of commission due to a stuck tubing anchor catcher, the higher the operational expenses become. Ongoing costs include maintaining the drilling site, paying salaries, and renting equipment. These expenses can quickly eat into the profitability of the project.
  4. Environmental Impact: Beyond the financial costs, a stuck tubing anchor catcher can have a detrimental environmental impact. Operators must carefully handle the recovery process or it can lead to leaks, spills, or other environmental hazards. These incidents can result in fines, regulatory penalties, and damage to a company’s reputation.

The Impact on Well Integrity

In addition to operational and environmental challenges, a stuck TAC can also permanently damage the wellbore and even create unsafe conditions for works. These impacts include:

  1. Wellbore Damage: Attempting to retrieve a stuck tubing anchor catcher can cause damage to the wellbore itself. The use of heavy equipment and aggressive techniques can lead to erosion or deformation of the wellbore, compromising its structural integrity. This damage may require costly repairs and further delay production.
  2. Safety Concerns: The safety of workers and the surrounding environment is paramount in the oil and gas industry. Stuck equipment can create safety hazards for those involved in the recovery efforts. Accidents or mishandling of equipment can lead to injuries or even fatalities, resulting in additional costs and tragic consequences.
  3. Long-Term Consequences: A stuck tubing anchor catcher can also have long-term consequences for the well’s performance. Damage to the wellbore or surrounding formations can lead to reduced production rates or increased operational challenges. Over time, this can result in decreased profitability for the well.

Preventing and Mitigating a Stuck TAC

While maintenance and training are always important in avoiding downhole equipment failures, the choice of TAC matters too. A standard TAC – with its large diameter and flat edges – creates an ideal spot for sediment and scale to build up. Stuck anchors are relatively common in this scenario. In contrast, the patented Slimline® TAC from TechTAC® features a smaller diameter and tapered flow subs on the top and bottom of the tool. This design reduces turbulent flow and directs solids out and around the anchor instead of accumulating on top of it. This increased flow-by capacity significantly reduces the chance of the TAC getting stuck in a well.

Slimline TAC from TechTAC

In the unlikely event that a Slimline® TAC does get stuck in a well, the anchor’s unique design allows it to be cutover in as little as 20 minutes – far less time than a standard TAC. Due to the smaller diameter, only the slip protectors and slips need to be cut over.

Conclusion

In oil production, seemingly minor issues like a stuck TAC can have far-reaching and costly consequences. The financial, environmental, and operational impact of such incidents underscores the importance of proactive measures and preparedness in the oil and gas industry. By prioritizing training and preventive maintenance – as well as considering the unique design advantages of TechTAC’s Slimline® TAC – companies can minimize the risks associated with stuck tubing anchor catchers and ensure the continued success of their drilling operations.

Pressure Drops in Oil Wells: Understanding the Causes and Impacts

A pressure drop within the wellbore of a well is both good and bad. The pressure drop between the reservoir and the wellbore that occurs at the perforations is the reason a well flows from the producing zone into the casing. However, anytime you have a pressure drop, you have a temperature drop and that can set up an environment where you begin to deposit iron sulfide and/or paraffin from the oil and precipitate scale deposits from the water. Not only does a well exhibit a pressure drop at the perforations but elsewhere in the casing. We will address that below and how the design of the Slimline® anchor can enhance well performance.

Oil rig operators

Causes of Pressure Drops in Oil Wells

A reduction in pressure within an oil well can be the result of a wide variety of issues. Some of those issues include:

  1. Reservoir Depletion: One of the primary causes of pressure drops in oil wells is reservoir depletion. Operators extract oil from the reservoir, which decreases its natural pressure over time. This natural depletion leads to a reduction in the driving force that pushes oil towards the surface. As a result, pressure in the well drops.
  2. Fluid Mobility: Fluid mobility is the ease with which fluids (oil, gas, and water) can flow through the reservoir rock. Operators need to carefully manage these fluids, or they can create pressure drops.
  3. Wellbore Damage: Damage to the wellbore itself can cause pressure drops. This damage may be a result of corrosion, scale buildup, or the intrusion of foreign materials into the well. Such obstructions can restrict the flow of fluids and reduce pressure.
  4. Temperature Variations: Changes in temperature within the reservoir and wellbore can affect fluid properties. When temperature drops occur, the viscosity of oil may increase. That increase makes it more challenging for the oil to flow, which can result in a pressure drop.

Impacts of Pressure Drops in Oil Wells

Monitoring and managing oil well pressure drops is important because those drops can have several negative impacts on production, including:

  1. Reduced Production Rates: The most immediate and noticeable impact of pressure drops in oil wells is reduced production rates. As the driving force behind fluid flow diminishes, the well’s ability to deliver oil to the surface is compromised. This can lead to decreased production and financial losses for operators.
  2. Increased Energy Costs: Operators may need to inject additional energy into the well to compensate for pressure drops. This often involves the use of pumps or compression systems, which can significantly increase operational costs.
  3. Reservoir Impairment: Excessive pressure drop within the reservoir can alter the relative permeability of the formation and can cause “water coning;” thereby reducing the production of oil through the reservoir and into the wellbore.
  4. Wellbore Damage: Corrosion and scale buildup, caused by changes in pressure and fluid composition, can potentially lead to costly repairs and safety hazards. In addition, scale, iron sulfide, and paraffin deposits initiated by the drop in pressure can plug the flow of oil into a pump or to the surface.

Unique Challenges with Sucker Rod Pump Systems

A tubing anchor catcher (TAC) secures the tubing string in deep wells that rely on a sucker rod pump (SRP) system for artificial lift. The TAC prevents unnecessary wear on the tubing string and the sucker rods. However, because the standard TAC can also restrict the flow of fluid through the annulus, it can create drops in pressure and temperature that can precipitate out scale, iron sulfide, paraffin and other sediment. With a standard TAC, that sediment can accumulate on top of the anchor and plant the entire string from being retrieved without an expensive workover.

Using the Slimline® TAC to Mitigate Pressure Drops

Slimline TAC from TechTAC

The patented Slimline® TAC from TechTAC® features a decreased diameter and tapered flow subs. That unique design increases flow-by capacity in the annulus by as much as 244% compared to other available TACs. This increased flow-by capacity reduces the flow regime from turbulent to a more laminar regime, thereby reducing those drops in pressure and temperature that can cause scale buildup and corrosion, which can grind production to a halt.

One senior completion foreman with a U.S.-based oil and gas company saw the Slimline’s impact firsthand. “We have one well that had to be pulled every 3 months due to scale,” he said. “After installing a Slimline TAC, we didn’t need to pull it for 2 years.” For this organization and many other production companies, installing the Slimline TAC was a simple change that mitigated the pressure and temperature drops that could lead to downtime and expensive workovers.

Gas Locking in Oil Wells: Causes, Consequences and Solutions

Gas locking in oil wells is a common challenge in the oil industry. In this article, we will delve into the intricacies of gas locking, its causes, consequences, and the solutions employed by the industry to mitigate its impact.

An oil rod pump

What is ‘Gas Locking’ in Oil Wells that also Produce Entrained Gas?

Gas that remains in the solution when the liquid enters the pump increases the volume of total fluid through the pump compared to the liquid measured at the surface by the formation volume factor at pump-intake conditions. The gas also decreases the density of the fluid and, thus, the head or pressure to be pumped against in the tubing.

Free gas that enters the pump must be compressed to a pressure equivalent to the head required to lift the fluid. This free gas will reduce the volume of both the produced liquid that enters the pump and the liquid measured at the surface. Any time the pump does not compress the free gas to a pressure greater than that exerted on the pump by the fluid column in the producing string, production ceases and the pump is said to be “gas locked.” This condition can exist in both plunger and centrifugal pumps.

Gas locking is particularly challenging in sucker rod pump (SRP) artificial lift systems. According to research from the Society of Petroleum Engineers, “Gas locking has been a problem accompanying the ball and seat sucker rod pump ever since its inception in the oil industry. A gas lock occurs when, contrary to the normal functioning of an SRP, due to a gas influx from the standing valve, the pressure exerted by the fluid below the traveling valve in the closed chamber does not overcome the weight of liquid column lying above the traveling valve in the pump barrel. This fails to lift the ball off the seat.”

Engineering resources from TechTAC

Why is Gas Locking of a Sucker Rod Pump So Detrimental to Production?

When a pump gas locks, the area in the pump barrel below the plunger contains mainly gas – and gas is a compressible fluid where oil is not. In this scenario, the hydrostatic pressure of the column of fluid and gas above the traveling valve of the plunger is greater than the compressed pressure of the gas below the plunger in the barrel of the pump. Therefore, on the downstroke, all that happens within the pump is gas compression and expansion.

Effectively, on the upstroke you have gas expansion, and on the downstroke you have gas compression. In both instances, the traveling valve ball remains on its seat with no new entry of oil into the pump on the downstroke, and subsequently, no new fluid produced into the tubing and displaced to the surface as production. Essentially the pump jack on the surface is just going up and down without any fluid produced to the tanks.

How Does the Slimline® Tubing Anchor Aid in the Reduction of Sucker Rod Pump Gas Locking?

The Slimline TAC can reduce or eliminate gas locking

When produced fluid and gas enters the casing from the reservoir via the perforations below the pump, it exhibits a pressure drop that causes gas to break out of the solution and rise towards the surface in the casing. With the increased flow area of the Slimline® design between the anchor OD and the casing ID (+244% over the standard anchor), the gas is able to be produced up the casing / tubing annulus rather than through the sucker rod pump where it creates the problems mentioned above. The standard tubing anchor catcher is a “choke-point,” causing restrictive turbulent flow. In contrast, the Slimline® from TechTAC®, with its tapered design and smaller diameter, allows for a laminar flowpath.

Conclusion

Gas locking is a common and challenging issue in the oil and gas industry that can have significant consequences for production rates and operating costs. Understanding the causes and consequences of gas locking is essential for oil producers to implement effective mitigation strategies. Among several possible solutions – from gas injection to costly workovers – one of the most cost-effective ways to mitigate gas locking in SRP systems is by deploying a Slimline® TAC from TechTAC®. The Slimline’s unique design dramatically increases flow-by capacity, which reduces the occurrence of gas locking by directing gas around the anchor instead of through the pump. By minimizing the frequency and impact of gas locking, production companies can significantly reduce cost, increase run time and increase the production of oil well operations.

CFD study graphic