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It’s an unfortunate fact of the industry that sometimes tools get lost down-hole. Some companies take an unconcerned approach to the issue, merely notifying you that something has gone missing. You’re left on your own to find a way to retrieve the items. We take a more proactive approach.

Renegade doesn’t just inform you that a loss has occurred down-hole, but we help you solve the issue. We use a variety of retrieval tools while fishing a lost BHA.

The advantage of Renegade is that we eliminate a lot of the usual headaches you encounter in a typical wellbore production environment. Instead of leaving you with unresolved problems, we get the job done right. Even if it’s something we don’t immediately know how to do, we don’t rest until we find the solution.

Pump Down Perforating

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Renegade Services TCP guns fired

Renegade Plug & Perf Services: A Better Experience

While pump down plug and perf operation may be only a small part of completions, it is critical that it is executed with precision and without creating the need for remedial work. Renegade has Plug and Perf specialists in every region of the U.S. equipped with specific local knowledge. Our goal is always 100% operational efficiency. Our equipment is meticulously inspected. We run comprehensive analytics before, throughout and after each job. We are known across the country for our fast response times and our over-the-top customer service.

Experience the Renegade difference today.

The Renegade Difference

We have a large truck fleet and always have additional equipment ready to deploy

We have multiple weight indicators, including wireless

We run 100% modular DIGITAL gun systems and intrinsically safe shooting systems.

Service support system – 24 hour on-call experts

Engineered modeling and reporting systems

Technology/service bundling options

Turn-key pricing

Renegade Services Pipe recovery – fracing




SOP information is reviewed with crews by management and made readily available to customers.

Pre-Frac Meeting with Crews

Customer Procedure

Downhole Modeling

Weight Indicator Calibrations by Engineers Completed and Presented to Management – Included in Job Folder

Cable Head Pullouts (Standard Cable) by Engineers Presented to Management – Included in Job Folder

Renegade Procedure – Including Job Specific JSAs

Equipment Inspections by Engineers and Crews

Job Equipment Loadout by Engineers and Crews

Cable Inspections – Internal Cable Book and Third-Party Reporting Made Available on All Trucks

Engineered Modeling System


Operating efficiency shared is with customers.

Weekly Job Summary Reports Shared In-person (ideally) or Digitally

360 Management Audit by Service Manager on Day 1

Utilization of BBS Observation Cards

Job Safety Assessments

Failure reports

  • Replace Detonators Crimpers and Cutter Blades
  • Inspect all Threads of Subs
  • Monthly Inspections
  • Documented Management Explosives Inventory


Extensive Post-Job information is shared with customers.

Job Report

Shot Sheets

Cross-Examined to Job Report

iScout Safety Document Such as BBS< RCA Report on Failures if Necessary

Operating Efficiency Updated for Customer and Company-Wide


Committed to 100% Intrinsically Safe Detonators  In Q4 of 2015 and 2016 when everyone else was switching to a less-safe, EB platform, we stuck with intrinsically safe shooting systems – We do not waiver on detonator quality and safety.

Implementation of Digital platforms and enhanced communication   Aradia/iScout instant notifications and reporting for management and customers. Our customers can define their desired alerts. Training programs for employees.  We’ve implemented regular training calendars for all roles

Extensive pre-job equipment checks facilitate safety and accuracy  Real-time reports are available. Before the job even begins, the Renegade pump-down crew calibrates all equipment.

SSE Mentorship Program  The Supervisors and co-workers must be able to readily identify Short Service Employee participants. Renegade Services assigns experienced employees to oversee the daily activities of those assigned to the SSE program to prevent work-related injuries and illnesses to new hires and temporary workers.

Company-wide AESC Gold Award for Safety  Renegade has received the AESC gold award for safety every year since 2017.

Streamline® Greaseless Line

  • Less friction compared to conventional non greaseless wireline, so longer lateral pump downs, less pick up weight off bottom.
  • Proven – Plug & perf, and pump down line
  • Less grease – no mess [HSE icon]
  • Pulling through rubber VS Pulling through flow tubes
  • No speed restriction


Renegade has adopted the IDC tool which is used strategically on highly deviated wells as a gun breaking system.

Applications include:

  • Highly Deviated Wells
  • Logging
  • Tractor operations
  • High-flow PL
  • Oriented Perforating
  • Gun Braking System

Renegade has Plug and Perf specialists in every region of the U.S.

Call us today for a live presentation and equipment consultation.

Well Integrity and Evaluation




Casing and cement are the foundation of any wellbore that are routinely overlooked. With the InSight™ Suite, casing and cement evaluation services build a data-rich reference model that hedges the risk of well problems that could ultimately jeopardize asset life. Alternatively, if casing or cement design strength looks to be compromised before work commences, these smaller issues can be remediated immediately instead of addressing compounded failures. Demanding well performance of today’s production requires efficient data gathering from a structural standpoint, and the InSight Suite packs a punch.

Whether you are adding the InSight Suite to part of a performance quality analysis sampling or a full-blown maintenance program, the value and density of information captured per trip is unmatched. Data-quality is the densest offering on the market today offering a no-gap, and dozens of data points per foot, even at logging speeds of over 7,000 feet per hour.

The tool string itself is lightweight and obtains rapid-fire information to build an integrity profile to reduce the risk of damage to the wellbore or the environment.


Cement Evaluation

Casing Evaluation

Injection Profile

NuWav Camera

Production Log Evaluation

Pulsed Neutron (RASP)

Spectral Noise/Temp. Evaluation




Casing and cement are the foundation of any wellbore that are routinely overlooked. With the InSight™ Suite, casing and cement evaluation services build a data-rich reference model that hedges the risk of well problems that could ultimately jeopardize asset life. Alternatively, if casing or cement design strength looks to be compromised before work commences, these smaller issues can be remediated immediately instead of addressing compounded failures. Demanding well performance of today’s production requires efficient data gathering from a structural standpoint, and the InSight Suite packs a punch.

Whether you are adding the InSight Suite to part of a performance quality analysis sampling or a full-blown maintenance program, the value and density of information captured per trip is unmatched. Data-quality is the densest offering on the market today offering a no-gap, and dozens of data points per foot, even at logging speeds of over 7,000 feet per hour.

The tool string itself is lightweight and obtains rapid-fire information to build an integrity profile to reduce the risk of damage to the wellbore or the environment.


Cement Evaluation

Casing Evaluation

Injection Profile

NuWav Camera

Production Log Evaluation

Pulsed Neutron (RASP)

Spectral Noise/Temp. Evaluation

Reaction is not an option in well development planning. Get ahead of tomorrow’s risk with strong references built directly into your programs.

 Whether you are adding the InSight Suite to part of a performance quality analysis sampling or a full-blown maintenance program, the value and density of information captured per trip is unmatched. Data-quality is the densest offering on the market today offering a no-gap, and dozens of data points per foot, even at logging speeds of over 7,000 feet per hour.

The tool string itself is lightweight and obtains rapid-fire information to build an integrity profile to reduce the risk of damage to the wellbore or the environment.

The most inclusive integrity evaluation available in a single run and an HD look downhole

Now available from Renegade Services

The service company you hire matters – Call us today for a live presentation and project consultation.

nuWAV camera

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NuWAV™ Downhole InSight™ Camera

Downhole InSight™ Camera: Bringing you real-time footage of what is happening below.

When problems occur, consultants make recommendations based on the data at hand. Renegade is taking the guess-work out of wellbore troubleshooting by adding one more piece of critical data

The Downhole InSight™ NuWAV™ camera provides quality video of conditions downhole, allowing problem identification such as a stuck object, a split within the casing, deviation and anything else that is visible from inside the wellbore. This unique wellbore camera provides real-time imaging by capturing high-resolution video of the borehole environment. This data helps geologists and engineers reduce drilling fluid losses, and make educated decisions about completions methods, retrieval of lost tools, and integrity issues with tubing and casing. The high-resolution NuWAV™ camera helps to mitigate the uncertainty of downhole operations, and supports the operator’s formation evaluation program. Imaging systems from Renegade are a cost-effective and efficient method for gathering detailed downhole data. 

This high-tech, versatile formation evaluation system is designed to gather the maximum amount of borehole imaging data. NuWAV™ is suitable for both conventional and deviated wells.

The imaging systems uses the latest optical sensor and state-of-the-art lens technologies to capture high definition images.


  • Can be deployed over mono-conductor or multi-conductor wireline.
  • Wide field of view unlike a standard image sensor that has a 4:3 or a 16:9 aspect ratio, Renegade uses a sensor with a 1:1 ratio meaning the camera has an impressive 180° FOV in both vertical and horizontal directions.
  • High light output by combining an ultra-sensitive image sensor with high-output lighting, NuWAV™ camera can see in the most challenging environments.
  • High-temperature rated to 257°F (125°C)
  • High-resolution high-definition and high-frame rate recording provides customers with a video of superior quality.
  • Light weight for easy transport and shipment.

Case StudIES

CASE STUDY: Downhole InSight™ NuWAV™ Camera identifies collapsed casing, helps customer determine well repair plans.

CASE STUDY: Downhole InSight™ NuWAV™ Camera Uncovers Failed Packer Retrieval


CASE STUDY: Downhole InSight™ NuWav™ Camera identifies obstruction in the well, decreasing critical NPT for the customer.


Let’s start the conversation about how Renegade and NuWAVTM can work for you.

Surface Vent FLOW (SVF), Sustained Casing Pressure (SCP), and Annular Flow Mitigation

Gas Migration

Statically, majority of surface gas behind casing can be attributed to variability in variable pressure gradients across varying geologic structures in the oilfield. Highly inconsistent surface formations can prove to be quite problematic down the road that even the most advanced slurries constantly fight. If the industry is faced with this indefinite problem, there must be a modern way to solve this after the cement sets?


At Renegade, we have been a part of the service industry for long enough to have witnessed the disconnect between asset integrity and service quality. The transfer of resources from one side of the balance scale to the other does not always equate to pro forma standards.

We are built on the foundation of a service provider operating as if we owned the assets. Knowing that micro-annulus gas migration problems are such a pervasive and expensive problem with potential to break field development apart at the seams, we knew there had to be a more effective way to stop gas influx without having to sacrificing future production.


Renegade has developed micro-annulus elimination service offerings around a pair of retrievable tools to provide an extremely simple, effective solutions.

CET – Casing Expander Tool™

Our Casing Expander Tool (CET) is a one-of-a-kind, refreshingly easy to deploy tool that performs localized permanent casing expansion to detent casing into the micro-annuli.

Simple. Permanent. Retractable. Zero Gas.

Renegade Wins Oilfield Service Company of the Year

In early 2018, Renegade Wireline Services won an award for oilfield service company of the year due to our operational excellence and improvements in productivity.

What is the award for?

The Oil and Gas Awards are awarded with the purpose of recognizing the achievements of companies within the oil and gas industry. Advances in various areas such as environment, innovation, efficiency, safety and health, and social responsibility are all considered and demonstrated through these awards.

Overall, the award recognizes the efforts of both individuals and corporations in the oil and gas industry.

The Award Categories

There are 25 categories awarded by the Oil and Gas Awards. This included:

    • The Award for Drilling Excellence
    • The Award for Excellence in Corporate Social Responsibility
    • The Award for Excellence in Health & Safety
    • The Award for Geophysical Excellence
    • The Award for Excellence in Environmental Stewardship
    • Consultancy of the Year
    • Future Industry Leader
    • E&P Company of the Year
    • Construction Company of the Year
    • Engineering Company of the Year
    • General Industry Service Award
    • Industry Leader
    • Industry Supplier of the Year
    • Manufacturer of the Year
    • New Technology Development of the Year
    • Law Firm of the Year
    • Kerr Pumps & FlowValve Award for Excellence in Well Completion


  • Risk Management Company of the Year
  • Workforce Housing Provider of the Year
  • Midstream Company of the Year
  • Recruitment Agency of the Year
  • Oilfield Services Company of the Year (Won by Renegade Wireline Services)
  • Water Management Company of the Year
  • Trucking Company of the Year


Renegade Wins the Award

Renegade Wireline Services was nominated for the Oilfield Service Company of the Year by an individual in Texas. Due to our advances in innovation, health, safety, and other topics, Renegade became a finalist in both Texas and Pennsylvania. In the end, we won the oilfield service company of the year in Pennsylvania.

The Northeast Oil & Gas Awards ceremony took place on March 1, 2018 in Pittsburgh where won the award among the following finalists within our category: McCutcheon Enterprises, Deep Well Services, and TechSolve.

The Texas Oil & Gas Awards ceremony took place on Wednesday, March 7, 2018. LineQuest and Basic Energy Services were the finalists in our award category.

Renegade plans on continuing to do our best to improve health and safety of workers and frac pad operators, keep the environment in tact through oilfield and gas well operations, and provide efficiency and innovation within the industry.


RigLock® Insights from Evercore ISI Energy – Oilfield Services, Equipment, & Drilling

In the May 29th, 2018 report industry analysts praise widespread RigLock implementation for its potential to increase field level efficiencies resulting in significantly increased profit.

Renegade Service’s RigLock stats as of July 2018:

  • Used in major shale plays for 2 years, since mid 2016
  • 116,898 + operating hours  
  • 45 units

EVERCORE ISI Industry-wide Sample Results:

  • Generates 1+ stage per day.
  • Saves 20-30 mins/stage
  • Annualized EBITA spread increase $4-5 Million

Renegade Services Results:

  • Generates 3+ stage per day.
  • Saves 30-45 mins/stage

“In a NAM oilfield environment where activity growth has steadied (yielding some near-term softness in the service spot market), it is up to the pressure pumpers to push the envelope on additional field-level efficiencies to drive incremental growth and profitability.” ¹

Renegade Services’ RigLock technology drives growth and profitability in two ways – significantly decreasing time between frac and wireline well swaps which results in stage increase per day and removing personnel from the red zone danger risk that comes with taking off and replacing the nightcap and lubricator assembly, 40 + feet in the air.

All else equal, and assuming no additional bottlenecks appear with widespread adoption of RigLock, we simplistically believe the incremental 20-30 minutes between well swaps could yield an incremental 1-2 stages/day. Our sensitivity attributes this incremental stage to ~$4-5 million in annualized EBITDA per spread, well above the levels needed to comfortably hit the vast majority of our pressure pumping out-year profitability levels.” 1

After being field-tested for more than 2 years with Renegade Services clocking 100,000+ operating hours on more than 45 units, investment firms, E&P companies, and wireline professionals alike are consistently realizing the significance of adding an extra stage. The efficiency gains the Renegade team has been able to produce since the widespread implementation supports Evercore ISI Energy’s assumption about RigLock potential.

“Admittedly, we were initially alerted of the substantial efficiency benefits of the RigLock by our E&P counterparts, but upon further engagement with the vast majority of pressure pumpers within our coverage, we quickly learned that RigLock is gaining appreciable adoption momentum in the Permian (and excitement is palpable regarding the potential efficiency gains).” ¹

RigLock use has substantially increased in the Permian and other NAM shale plays in the last several months as pressure pumpers continue to report significant ROI in efficiency gains with RigLock despite the highly commoditized stigma of the current market. Renegade is the leading supplier of RigLock packages across the Marcellus and the Permian.

Furthermore, it is our opinion that RigLock gains are very much a function of how efficient the particular E&P/service provider was before during well swap operations.” ¹

RigLock gains are definitely influenced by the level of service providers’ efficiency, and Renegade Services provides the expertise needed to maximize RigLock efficiency gains.

Renegade helped create RigLock and has the most worldwide field experience, Renegade Services ran the inaugural RigLock package, many competitors in the wireline arena choose Renegade crews for their RigLock work.  Renegade Services has broken records in efficiency completing more stages per day than ever before. We are the leading service provider for RigLock with the most in-depth maintenance program lead by our dedicated, FHE trained RigLock technicians.  RigLock has been on location for over 98,400 operating hours on more than 45 units (June 2018) with Renegade Services. You can trust our expert-trained wireline team for your project.

“Conclusion – too early to tell, but 20-30 minutes/swap could unlock an incremental stage/day and upwards of ~5.0 million in annualized EBTIDA/spread. All else equal, and assuming no additional bottlenecks appear with widespread adoption of RigLock, we believe the incremental 20-30 minutes between well swaps could, over the course of a day, yield an incremental 1-2 stages/day (in reality, the improved throughput places more strain on other parts of the completion value chain, so likely a naïve assumption to draw). On an annualized EBITDA basis, the RigLock efficiency gain is dependent on stage pricing, but we see a path toward upwards of $4-$5 million in EBITDA/year per spread.”

Renegade Services is the world’s leading RigLock service provider resulting in our crews achieving record gains of 3-4 stages/day with as low as 15 minutes between well swaps.

Given gaining 1 stage per day with RigLock can result in a 13% increase in EBITA and a potential annualized EBITA spread increase of $4 – 5 Million, would there be any reason you wouldn’t consider saving time and increasing profits with RigLock today?


Want to learn more? Call us today at (806) 897-0735


precision, complete, comprehensive, P&A (Plug and Abandon)

There comes a point when the work on every well-bore operation is complete. Everything that can possibly be extracted from the site has already been done. But closing up the operation requires just as much careful attention as the first part of drilling, if not more so. You need to do things the right way so that it doesn’t leave behind environmental damage and risks of future problems. Such problems can happen for a variety of reasons, but we want to do as much as we can to minimize our possible involvement.

That’s where the plug and abandon stage of production comes into effect. Renegade Wireline Services plays an important part in this process. We shoot the squeeze holes, set plugs, and dump bail cement to aid in the abandonment of a well. Getting this part right is very important in order to protect the freshwater zone.

This process involves multiple steps. We do not simply pump cement and leave. Doing it properly means taking every step to try to prevent oil well leaks in the future. At the same time, because the field is mature, it’s also important to manage costs and time.

We take the same care at this stage as we do during completions or any other phase to cautiously manage time and costs to help our customer avoid unnecessary expenditures during the final days of closing up the site.

Renegade Wireline Services is with you throughout the entire process. From managing your operation to successfully and thoroughly closing up the well-bore to repairing any sustained casing pressure or annulus that may be detcted. Renegade Services has the technical expertise to get the job done right and the commitment to your specific project.


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Get Better Real-Time Information with eLine.

A well-site is a fluctuating and dynamic environment. Successful operations depend on having access to real-time data to allow you to adapt to changing conditions as soon as possible. Renegade Wireline Services uses an electric line to provide the most accurate data capabilities possible.

The insulated cable is surrounded by multiple strands of wire called armors. This conductive wire provides a great way to send signals down the hole for a variety of purposes. You can initiate guns, plugs, or other devices. Some line is made of nickel, which is designed to survive in hostile environments such as CO2 wells.

The benefits of this line are related to how well they work in conjunction with other tools commonly used on a well-site. These tools include the casing collar locator, which responds to changes in metal volume by producing low-frequency voltage in a coil mounted between two magnets. Another tool that benefits from the electric line is the downhole electric cutting tool, which is a safe way to cleanly cut tubing with precision and without dangerous chemicals or explosives. The compensated neutron log measures the presence of hydrogen to determine the porosity of the formation. eLine is the key component that brings everything together to work efficiently and powerfully in production. It makes your tools function more effectively and serves up all the data you need from your operation.

Count on Renegade Wireline Services to know and use the right components for your job down to the smallest details.



A few examples of our eLine tools include:

  • Casing Collar Locator (CCL): Responds to changes in metal volume, such as pipe collars and perforations. As the tool passes a collar, or change in metal volume, lines of magnetic flux between two opposing permanent magnets are disturbed, causing a low-frequency voltage or an electromagnetic field to be induced in a coil mounted between the permanent magnets. Finally, the signal is converted into a readout for interpretation.
  • Downhole Electric Cutting Tool: This is a safe and reliable tool for cutting tubulars cleanly with precision without hazardous chemicals or explosives.
  • Compensated Neutron Log (CNL): Measures the formation porosity based on the presence of hydrogen in the formation. It is comprised of a radioactive source of either Cf or AmBe isotopes and a set of two detectors.

Stuck Pipe Logging

» Radial Stuck Pipe Log Sample.


The stuck pipe log uses acoustic measurement techniques to provide a continuous record and evaluation of a stuck pipe string.

This logging service can be performed through drill pipe, casing, or tubing to identify problem areas.

Acoustic pulses, initiated at the instrument’s transmitter, travel through the pipe string and are measured at the receiver. The acoustic energy level at the receiver is proportional to the degree of stuck pipe. Similar to conventional cement bond logging measurements, low attenuation readings indicate free pipe and high attenuation readings indicate stuck pipe.

The stuck pipe log is superior to a free point evaluation because the stuck pipe log is used to determine multiple stuck points throughout the well instead of only the first problem area. With a complete picture of the situation at hand, an informed decision can be made as to how best proceed in the pipe recovery operation, potentially saving many hours of time and money.


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Renegade Service: The pioneers of RigLock®, the original hands-free, remote hydraulic wellhead latch assembly

Remove the person from the risk.

Renegade Services continues to innovate and implement new levers of wellsite efficiency and safety with the RigLock remote hydraulic wellhead latch assembly. Developed in conjunction with FHS, RigLock removes wellsite personnel from dangerous situations handling heavy, cumbersome equipment at heights near high-pressure lines.

Riglock is a hydraulically-controlled, remote operation device that can connect the lubricator to the well with the flip of a switch. It allows you to remotely connect and disconnect the wireline lubricator. RigLock uses hydraulically operated dogs that lock the lubricator in place and a lockdown ring that mechanically holds the dogs in place. The position of the lockdown ring can be seen from anywhere on location. It also uses a built-in funnel to make it very simple for a crane operator to make a connection.

RigLock utilizes a tapered wedge/spring design and a hydraulically actuated lock ring resulting in industry-leading standards of safety and remote wellsite management sophistication not available with current systems. Crews work from a safe distance, away from the red zone, with but with clear visibility of connection or disconnection operations.

Previously frac operations required the nightcap to be removed manually from the frac tree to stab the wireline lubricator onto the well. This involved a person working on a lift, manually performing the operations. This was done in an exclusion zone, directly underneath a suspended load with hands on the equipment being lifted. RigLock removes the person from the risk.

  • Extractor feature can pull and insert the nightcap remotely.
  • Decreases time it takes to stab onto the well from 25 minutes to only eight minutes.
  • During zipper fracs, wireline operations can proceed from one to well to another while pumping operations continue uninterrupted.
  • Optimized RigLock now an integral part of oilfield operations.


At the center of the RigLock system is a simple and safe control unit. The well pressure monitoring system quickly and accurately display operating pressure and includes built-in unintentional unlock prevention.  A digital, operator-designed touchscreen with cellular connectivity puts the RigLock control unit at the forefront of wellsite safety and efficiency. 

RigLock® Control Unit Features
Well Pressure Monitoring System System Power/Pressure Console Safety Lockouts Solar Panel for On Board Power Storage Retractable Hose Reels Perkins Diesel-Hydraulic Power Unit with Air Compressor

Well Pressure Monitoring System

System Power/Pressure Console

Safety Lockouts

Solar Panel for On Board Power Storage

Retractable Hose Reels

Perkins Diesel-Hydraulic Power Unit with Air Compressor

Key Features of RigLock®
Nightcap Oversized highly visible entry guide. Mechanical Locking Ring secures the cams. Cam locks secures equipment connection. Manifold to test integrity of connection. Accessible Hydraulic Hook-ups. Integrated 2 inch 1502 pump-in sub. Flange connection to the wellhead.


Contains pressure and keeps foreign material out of the frac tree between stages.

Oversized highly visible entry guide.

This allows the crane operator to quickly spot the sub going into RigLock® from distances of over hundred feet, ensuring proper equipment placement. RigLock® speeds up all well work with quickly connecting and disconnecting.

Mechanical Locking Ring secures the cams.

The locking ring goes over top the cams giving us a secondary lock and thus ensuring the integrity of the connection even during possible loss of hydraulic power.

Cam locks secures equipment connection.

The patented design uses a series of 6 cams to both seat the sub, secure a good connection, and to allow the locking ring to come over the top of it, thus sealing RigLock® to the wellhead.

Manifold to test integrity of connection.

The quick test sub portion of the RigLock® body enables you to test the connection from the control unit on the ground before well pressure is introduced to RigLock®.

Accessible Hydraulic Hook-ups.

Hydraulic quickly connects to RigLock® so that we can quickly make the connections to function the cams the locking rings and the quick test sub. Remote hydraulic actuation keeps technicians away from possible collision or crushing injuries.

Integrated 2 inch 1502 pump-in sub.

This allows for equalization and to pump into the lubricator from below RigLock®.

Flange connection to the wellhead.

These flanges come in different orientations and sizes so that you can easily install RigLock® on any well head.

The Future of RigLock® Innovation

RigLock® changed the oil and gas industry significantly, much like the combustion engine changed the industry of transportation. As we continue to deploy more systems every month, we continue to pioneer new products to expand its efficiency and safety.

Today there are several enhancements to the RigLock® that were not available when the product initially launched. These enhancements to the product make it both safer and more efficient.

Eventually, we believe we will see this package on every well head around the world. We anticipate the RigLock® will fundamentally transform the way completions activities are done on oil or gas well sites.


“We greatly value our relationship with Renegade Services. They provide a quality experience to their customer with a unique and innovative approach.”

—Nick Snoke

Engineered for the Extreme Conditions of High-Pressure Operations

The RigLock® 15K conquers the challenging environments of high-pressure well operations with 3 levels of safety. Well intervention teams, responsible for high-pressure operations, will benefit from increased productivity while improving safety on location. The engineered construction is composed of a limited number of moving parts which reduces maintenance time and improves operations while also increasing usability. With the RigLock® 15K, the adapter or night-cap initiates the connection. The hydraulically actuated lock ring lowers to complete it.

RigLock® 15K Features:

The RigLock® 15K remotely connects surface equipment to the wellhead for high-pressure wells.

  • Designed specifically for superior performance on high-pressure well operations.
  • 3 levels of safety to protect personnel, equipment, and business relations.
  • Four tapered wedges initiate the seal once the adapter or night-cap is received into the RigLock.
  • The lock ring hydraulically lowers over the tapered wedges completing the connection.
  • The oversized, highly visible entry guide ensures crane operators can properly place equipment.
  • By working remotely, technicians lock and unlock the RigLock® from a safe distance eliminating the possibility of injury.

RigLock® 15K Control Unit Features:

  • Advanced sensors with light indicators ensure proper closure to prevent operators from applying pressure prematurely.
  • The powerful, lightweight VMAC hydraulic driven air compressor generates 140 PSI and produces 30 CFM.
  • Powered by a Tier 4 Final diesel engine that runs clean and quiet.

A RigLock® is Ready for You

Let’s start the conversation about how the RigLock wellhead latch and ball drop system and Renegade can work for you.

IDC Tool

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» IDC Tool.

IDC Tool

The Insulation-Displacement Contact (IDC) tool is designed to limit or control the movement of a tool string within the wellbore. This may be required to prevent a logging tool being blown up-hole, along the wellbore by fluid flow, or to hold a tool in place on an incline.

Special slips are available to enable the IDC to act as a gun braking system in the wellbore. The arms of the IDC provide an axial resistance to movement within the wellbore of approximately 300lbs, depending on well pressure. The tool is addressable and therefore multiple IDC tools can be deployed within a string.

The only restriction on placement is that each tool should have direct access to a cable conductor. The IDC requires only one conductor and ground for activation and employs a robust, field proven telemetry system designed for fail-safe operation.

The tool’s electronics can withstand up to 1000vac/1000vdc on its operating conductors. In the event of loss of communication to the tool, it can be withdrawn from the well through restrictions by closure of the load spring or shearing of the arm retaining pins.



  • Highly Deviated Wells
  • Logging
  • Tractor operations
  • High-flow PL
  • Oriented Perforating
  • Gun Braking System


Call us today for a live presentation and equipment consultation.

The Service Company You Hire Matters

SWAT Spectral Well Analysis

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» Record of Spectral Well Analysis.



Records entire spectrum of all natural emitting gamma rays and previously injected isotopes during stimulation (frac). Each isotope energy level, measured in electron volts (KeV), is simultaneously recorded at the surface.

The resulting spectral provides vital data to determine the placement of all frac fluids and/or proppants.

The spectral survey can be observed on a remote monitor while the downhole spectral survey is being recorded. Does not have to retrieve spectral gamma ray from downhole before getting survey results.

Other services recorded on same trip downhole are correlation gamma ray, temperature survey, and collar log for depth control with other surveys.

Isotopes Commonly Used for Tagging

Isotope                 Half-Life                 Gammy Ray

Energy (KeV)

Iridium-192           74 Days                 317,468,604

Scandium -46       84 Days                889,1120

Antimony -124      60 Days                603,1691

Iodine -131           8 Days                  364

No Wash ISO Seal

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(IsoSeal-3) “NO WASH” is designed to eliminate radioactive residue in fluids or tubular goods in wells while being fractured, acidized, or cemented. The basic material (beads) has a lower density and higher sheer stress tolerance than other types of products being used. This material will not soften or disintegrate when immersed in liquids.

Proprietary processes are used to develop IsoSeal3 “NO WASH” into a superior product by a three-step formula.

I. Absorbent material (beads) are applied with appropriate compounds to make the desired radioactive isotope. (Examples: Iridium-192, Scandium-46, Antimony-124)

II. Sealant is applied by a special process to ensure complete encapsulation.

III. Sealed, encapsulated beads are shipped to a nuclear reactor for radioactive activation.


Has a lower density for use in almost all downhole frac or acidizing jobs.
Minimizes flowback of radioactive beads because it is made of solid particles with high shear tolerance.
Has low density, allowing for injection on the down stream side of frac or acid pumping equipment. This eliminates the possibility of a service company’s equipment becoming contaminated.
(IsoSeal-3) “NO WASH” has combined these features to allow longer periods before logging.

Radioactive Tracers Offer a Closer Look at Horizontal Completions

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Radioactive Tracers Offer a Closer Look at Horizontal Completions, David Holcomb World Oil, November 1991.


Completion techniques can be analyzed using gamma ray emitting isotopes and spectral gamma ray logging. Examples of Austin Chalk and Bakken Shale evaluations show how operators can qualitatively compare stimulation and diversion effectiveness, and completion methods by using tracer technology.

Radioactive tracer tagging during stimulation treatments on vertical wells has been in use for many years and applications have been discussed in literature. More recently, multiple radioactive tracers have been employed to help evaluate various aspects of well stimulation. They have become standard industry practice for evaluation of treatment containment, fracture height growth, channeling behind casing, fracture initiation from perforations, diversion, and acid or proppant distribution.

The Determination of Fracture Orientation Using a Directional Gamma Ray Tool

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The Determination of Fracture Orientation Using a Directional Gamma Ray Tool, J.L. Taylor, III, et al, SPWLA 91-AA, June 1991.


The effectiveness of hydraulic fracturing operations is commonly evaluated by tagging the materials pumped downhole with one or more gamma-ray-emitting isotopes and subsequently logging the borehole with a gamma ray spectroscopy tool. Many times it is very desirable to also determine the orientation of the fracture planes. This paper describes a directional gamma ray tool which makes this possible.

The main tool component is a sodium iodide scintillation detector within a rotating tungsten shield containing a slotted aperture. A three-axis accelerometer is used to determine the direction of the gravity vector relative to the tool axis. The 1-11/16-inch-diameter toolstring consists of a gamma ray spectroscopy tool and a directional gamma ray tool. Optionally, a direction gyro survey tool may be attached.

The logging procedure is first to run the spectroscopy tool to determine the distribution of tracers. This allows depth intervals to be selected for stationary measurements and moving runs with the directional tool. Example logs from prototype tool field test illustrate the effectiveness of the directional gamma ray measurements. These results show that many gamma ray maxima exhibit significant azimuthal asymmetry. The interpretations of these asymmetries are discussed and compared with laboratory measurements.

Gamma Ray Tracers Help Evaluate Acid Diversion

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Gamma Ray Tracers Help Evaluate Acid Diversion, J.L. Taylor, III, et al, Petroleum Engineer International, February 1990.


The use of multiple gamma ray tracers has helped evaluate acid diversion in several North Sea completions. The use of multiple radioactive tracers and subsequent logging with advanced gamma spectroscopy techniques offers a cost-effective and convenient method for direct measurement of vital stimulation parameters such as diverter effectiveness.

Productive intervals in the Norwegian sector of the North Sea tend to be quite thick: Danian pay ranges up to 550 ft, and Maestrichtian up to 500 ft. Average porosity can reach 48%, and matrix permeability varies from less than 0.1 to 5 md. Well productivity seems dependent on the degree of natural fracturing, and pressure transient testing derived permeability estimates can be as much as 75 times the matrix permeabilities obtained from core measurements.

Perforations are placed in 10-to 20-ft clusters spaced 40 to 80 ft apart, with a shot density of 2 shots/ft throughout each cluster. The acid stimulation treatments are then pumped in multiple stages, with each stage consisting of a viscous pad, acid, overflush, and diverter (ball sealers are most often employed).

The tracer studies outlined in this article were conducted on six stimulation treatments to determine if the diverter techniques employed result in relatively even treatment of all pay, and to evidence the creation of multiple hydraulic fractures. All evidence suggests adequate diversion usually occurs and new fractures are propagated on each stage.

The specific tracer technique used involved the placement of a different discernible gamma emitting tracer in each stimulation stage to determine its relative placement and thus infer the effectiveness of the diverter stages. Three tracers, Antimony (124Sb), Iridium (192Ir), and Scandium (46Sc) were added to each stage to differentiate the placement of up to three stages or groups of stages. Following each treatment, a Prism® log was run to identify tracer placement. A detailed description of the materials used and the tagging and logging techniques were discussed in earlier articles.

The tracers were prepared as ceramic particle encapsulations, with a mean particle size of 0.5 mm. This proprietary preparation exhibits a tracer washoff of less than 0.01% in 28% HC1 at 100xC, and has a specific activity of approximately 0.89 mCi/gm (32.8 MBq/gm) or 0.0014 mCi/particle (0.0527 MBq/particle). The use of these tracers in particulate form was preferred to using soluble forms to minimize environmental concerns of returning radioactive residue to the surface with the flowback of the spent acid. The tracers and the equipment used to inject them into the stimulation process were transported to the well platforms from the UK aboard the service company’s vessel performing the treatment. Generally, about 20 mCi (740 MBQ) of each tracer was injected continuously throughout each acid stage. Specific licensing to perform the radioactive tracer studies was required from Norway’s National Institute of Radiation Hygiene.

The wells were logged using a 1.6875-in. (4.2863-cm) OD Prism tool, which contains a 1-in. by 6-in. scintillation crystal. The logging speed was 500 ft/hour (152.4 m/hour). At each 3-in. (7.62 cm) interval, the entire 256-channel gamma ray spectrum was encoded and transmitted to the surface and recorded on magnetic tape. This data was subsequently processed using the proprietary software on a microcomputer at a log analysis center in Stavanger, Norway. The software mathematically unfolds the gamma ray spectrum to determine tracer yields and indicate the location of individual isotopes along the wellbore. Furthermore, the program determines the lateral tracer placement (inside or outside the casing) by using a photopeak to downscatter ratio.

The results of the six tracer studies are presented in tabular form in Table 1. The Prism logs from wells A, B, and C are presented as Figs. 1,2, and 3, respectively.

In summary the following conclusions are made:

Tracer materials of the type and packaging used are effectively placed in the formation and do not flow back into the well. In consequence, reliable Prism data may be obtained in one pass after cleanup flow of the well.
Where the cement bond log indicates effective mechanical isolation of perforated zones in the treated interval and the number of perforations is low, good diversion occurs.Breakdown of both single and multiple zones on individual stages were observed.
Limited fracture heights and formation of multiple fractures occurs.
Tracer material positioned during the early treatment stages is partially stripped away during the later stages. This is particularly apparent when the number of perforations is low and flow velocities will, in consequence, be high.
The logging technique and analysis allows us to determine the placement of isotopes in the presence of radioactive scale.

Tracers Improve Hydraulic Fracturing

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Tracers Can Improve Hydraulic Fracturing, J.W. Chisholm, Petroleum Engineer International, July 1989.


Because the success of well stimulation treatments often dictates the economic justification of petroleum field development, much effort has been devoted to the measurement of various parameters associated with this critical and costly operation. Specifically, the prediction, measurement, and optimization of induced hydraulic fracture geometry is an endeavor which has resulted in a major industry-wide research effort. in the past 10 years, extraordinary advances have been made and the evolution of well stimulation technology is still proceeding at an incredible rate.

Many methods of actually measuring or inferring fracture geometry during or after a frac treatment have been developed and tested; however, few are considered sufficiently pratical, convenient, and cost-effective to be performed routinely. Analysis of pressure data from frac treatments and prefrac injection tests can lead to quantification of certain fracture parameters such as closure stress, fluid efficiency, and leakoff coefficient; however, computation of most of these properties requires knowledge of the vertical fracture height.

Of all the available vertical fracture height measurement techniques, post-treatment tracer and temperature surveys are by far the most common because they are convenient and relatively inexpensive to conduct. Temperature surveys can provide quantitative vertical fracture height determinations; however, they are plagued by the following problems:

Cross flow and pressure-induced fluid redistribution following the treatment can result in temperature surveys that are difficult to interpret.
In wells where the formation temperature differs only slightly from the surface ambient temperature, these surveys are not possible.
If significant amounts of proppant remain in the wellbore and must be circulated out before logging, the circulation process may distort the temperature anomalies created by the frac treatment, or the temperature anomalies created by the treatment may completely dissipate by the time the temperature survey can be conducted.
Because of these problems, particularly the last, frac treatments are frequently tagged with radioactive tracers. The major objections to using gamma emitting tracers have been that:

Only single tracer operations were pratical, unless tedious multiple logging runs using tracers with greatly differing half-lives were conducted.
A conventional gamma ray log cannot differentiate tracer material actually placed in the formation from residual tracer left in the wellbore; thus, the determination of actual vertical fracture height is often obscured.
The depth of detection from the wellbore is limited to less than a meter unless excessive concentrations of radioactive tracer are employed.

Using Tracers to Evaluate Propped Fracture Width

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Using Tracers to Evaluate Propped Fracture Width, S.A. Holditch, David Holcomb, Zillur Rahim, SPE 26922, November 1993.


Using Tracers to Evaluate Propped Fracture Width

Many production engineers are beginning to use three-dimensional (3-D) fracture propagation models to design and analyze hydraulic fracture treatments. To use a 3-D model, one must define the layers that comprise the reservoir and develop detailed datasets that accurately describe the layers. The data that are critical for designing and analyzing hydraulic fracture treatments are in-situ stress, formation permeability, formation porosity, reservoir pressure, and Young’s modulus. Many times, these parameters can be determined from logs and/or correlated to lithology.

Once the datasets are obtained, one can use a three-dimensional fracture propagation model to estimate values of created or propped fracture length, width, and height. To understand and improve the fracture design process, the engineer must confirm the estimates of fracture dimensions that are predicted by a fracture propagation model. To verify the model, one must analyze field data to be sure the field data are consistent with the model results. For example, the net pressure predicted by the 3-D fracture propagation model should closely match the net pressures observed in the field. When net pressure is adequately matched, we usually find that the overall created fracture dimensions predicted by a 3-D fracture propagation model are reasonable. To determine estimates of propped fracture length, one must also analyze post-fracture production and pressure transient data. Because of fracture fluid cleanup problems, we often find that values of propped fracture length generated by analyzing field production data are much shorter than the created fracture length predicted by the fracture propagation model. Detailed engineering studies are often required to reconcile the differences.

To directly measure values of fracture width, one must perform a fracture treatment in openhole, then use a downhole imaging tool to “see” the fracture. Such an approach is not usually practical. In this paper, we will describe a method to qualitatively estimate the propped width profile at the borehole that uses radioactive tracers. Confirming the propped width profile generated by a model with field data can be very beneficial and informative.

We have found that the use of zero wash radioactive tracers can help us learn both (1) where the fracture fluid is going and (2) where the proppant resides in the fracture near the wellbore. Assuming the level of radioactivity is proportional to volume, then the level of radioactivity will also be proportional to the propped fracture width. As such, one can obtain qualitative estimates of propped fracture width at the wellbore using a radioactive tracer where the strength of the radioactive signal is proportional to fracture volume near the wellbore.

The objectives of this paper are to discuss what factors control the fracture width profile and how to obtain data to compute fracture width. We also explain how one can use radioactive tracers to develop data that can be analyzed to determine qualitative estimates of propped fracture width. Finally, we provide several examples to illustrate how one can use estimated values to calibrate a 3-Dimensional fracture propagation model.

The information described in this paper can be used by a production engineer to obtain a better understanding of a specific hydraulic fracture treatment. As our understanding of hydraulic fracturing improves, we should be able to design the optimal fracture treatment with more certainty. When we design and pump the optimal fracture treatment, we maximize the economic return on developing oil and gas properties.

Tracers Facilitate Stimulation Job Evaluation

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Radioactive Tracers Facilitate Stimulation Job Evaluation

Logging tools can now quantify multiple isotopes, including the volume of individual isotopes present and their radial position away from the wellbore. In conjunction with those improvements, tracers have been developed that eliminate “wash off” effects of conventional tracers. By precisely locating the presence and concentration of traced proppant at the wellbore, better evaluations can be made of vertical and radial proppant distribution near the wellbore and fracture aperture width.

A comprehensive study of 98 wells with 136 fracture stages in four different basins has been completed. Each stage was traced and logged. Spectral gamma ray logs were compared with conventional openhole logs, sonic stress logs where available, and cased hole logs such as cement bond and production logs. This data was then compared on a well-by-well basis with the fracture design program, post treatment stimulation reports, and production history.

Several trends were identified while building this massive stimulation evaluation database. Problems that potentially could be solved using tracer technology are:

  • Fracture height greater than design
  • Unstimulated perforation sets within a stage
  • Understimulated pay intervals


Using Tracers For Monitoring And Diagnosing Horizontal Well Stimulations

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Using Tracers for Monitoring and Diagnosing Horizontal Well Stimulations, David Holcomb, Robert A. Woodroof, World Oil Horizontal Well Completions Symposium, 1996.

The application of multiple radioactive tracers (Zero Wash®) and spectral gamma ray imaging has allowed for improved diagnostics of stimulation treatment distribution. Whether acidizing and diverting or fracturing and proppant placement, multiple tracers (i.e.; Iridium-192, Scandium-46, Antimony-124) have allowed operators to better analyze proppant entry with respect to stage, volume, and/or type placed across lateral intervals, as well as acid entry and distribution in order to better understand and optimize treatment techniques such as diverting, rates, stage sizes, etc.

Holcomb and Read demonstrated that tracers were useful in evaluating Austin Chalk and Bakken Shale completions in South Texas and North Dakota respectively. Qualitative comparisons helped operators understand stimulation coverage and diversion effectiveness.

Problems still plague the use of tracers in horizontal wells and usually center around uncemented or poorly cemented casing. Tracer materials can accumulate behind pipe in depressions or washed out sections even if acid or slickwater treatments are overflushed. While this may make tracer images more difficult to interpret, it does not rule out their usefulness for identifying potential problem areas. Open hole horizontal completions have also posed problems for tracers due to wash-off of tracer materials and adsorption onto rock, not necessarily associated with fracture entry. Improvements made in horizontal well drilling and completions have been aided by the reliability of improved Zero Wash® tracer carriers and spectral imaging tools to provide a more quantitative look at stimulation treatment placement across horizontal well sections without the problems associated with wash-off and subsequent adsorption onto rock, casin, liners, etc.

One particular application has been noted with tracers used to confirm the success or failure of various diverting techniques to allow lateral zones to be completely acidized. Different Zero Wash® tracers are placed in different stages of acid separated by various diverter stages using such materials as oil soluble resins, gel pills, ball sealers, benzoic acid, rock salt, crushed Unibeads®, or foams. Three tracers are usually used in a variety of carrier sizes, densities, and non-wash/crush/abrasion-loss formats. They include Iridium-192, Scandium-46, and Antimony-124, with half-lives varying from sixty to eighty-four days.


Circulating Pyro Torch

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» Picture #1

2.875 in. tubing; 1-1/2 in. CPT produced 1 hole; appx flow area 0.625 inches squared @ 20Ksi

» Picture #2

4.5 in. tubing; 2-1/2 in. CPT produced 1 hole; appx flow area 1.01 inches squared @ 20Ksi

» Picture #3

5 in. tubing; 2-1/2 in. CPT produced 1 hole; appx flow area 1.01 inches squared @ 20Ksi


MCR Oil Tool’s circulating pyro torch was developed using the same principles as the successful and field-proven radial cutting torch (RCT) system. In most conditions, adequate flow into the annulus is required when expecting a successful cut while running an RCT job. Explosive perforators and punchers are not reliable at producing consistent holes that provide sufficient flow, having a dramatic effect on success when cutting with the RCT. MCR’s circulating pyro torch delivers the required annular flow prior to cutting and provides a consistent and reliable punch in coil tubing, casing, and drill pipe. By utilizing the latest in MCR’s proprietary non-explosive, non-hazmat rated fuel technology, you can complete your job faster and safer than ever before.


  • Non-explosive
  • Non-hazmat rated fuel
  • Radio safe
  • Operates in temperatures up to 500°F (260°C) & pressures up to 25,000 psi (172.4 MPa)
  • Perforates all steel, high chrome, & plastic coated tubulars
  • Perforates in exotic fluids or dry pipe
  • Single/dual perforations in sizes from 0.38 in. (insert inches squared 2) to 7.0 in. (insert inches squared)
  • Deployable within hours and not days
  • Minimizes downtime and associated costs



MCR’s circulating pyro torch assembly is lowered into the well to the desired depth. MCR’s  thermal generator ignites and activates the primary fuel load causing an increase in internal pressure. Following internal pressure rise, plasma exits the torch which perforates the target pipe. By design, the CPT cutting jet forces the tool against the wall of the pipe; the high frictional forces between the CPT and the wall of the pipe are greater than the thrust forces exerted by the pressure bubble, stabilizing the perforator to make the cut. It is this feature that allows MCR’s perforators to function properly in plugged pipe situations.


  • Standard applications
  • Undersized for restrictions
  • HP-HT environments
  • Custom tools available




  • Safely dissipates all thermal generator energy in the event of operator activation error on surface



  • Data logging tool and firing system; safely enables all MCR cutting systems

Radial Cutting Torch

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MCR Oil Tool’s radial cutting torch (RCT) is a patented cutting device used to sever tubing, casing, drill pipe, and coiled tubing without the use of explosives or hazardous materials, making it one of the safest pipe cutting tools on the market. Using advanced technology, the patented nozzle and proprietary mixture of various powdered metals produces jets of highly energized plasma to cut virtually any type of pipe in any well condition. Because the RCT does not use explosives or hazardous chemicals, the tool can be shipped almost anywhere in the world within 24 hours, saving significant time and associated costs, while remaining compliant with safety regulations.


MCR’s radial cutting torch assembly is lowered into the well until desired depth is reached. MCR’s thermal generator ignites and activates the primary fuel load; highly energized plasma is produced causing an increase in internal pressure. Once the pressure produced inside the torch exceeds that of the wellbore, the protective sleeve is displaced exposing the nozzle to the wellbore. Plasma exits thru the nozzle to sever the target in drilling, completion, or production scenarios, with wellbore temperatures up to 500° (260°C) and pressures to 20,000 psi (137.9 MPa).


  • Standard applications
  • Undersized for restrictions
  • HP-HT environments
  • Cutting up to 9-5/8 in. casing
  • Custom tools available
  • Non-HazMat rated RCT’s currently available:
  • RCT-SP




  • Anchors during cutting operation – available for E-Line, 1-1/2 in. to 4 in. RCT system deployments


  • Safely dissipates all thermal generator energy in the event of operator activation error on surface


  • Data logging tool and firing system – safely enables all MCR cutting systems



Picture #1 Picture #2 Picture #3 Picture #4 Picture #5
3 – 1/2 in. Hastelloy 5 1/2 in. 26# 25% Chrome 7 5/8 in. 33.7# L80 9 5/8 in. 59.4# L80 2 7/8 in. 10.7# 70% Glycol
RCT – 2500 – 300 RCT – 3375 – 400 RCT – 5000 – 300 RCT 7000 – 300 RCT – 1500 -999 XP
cut @ 11,000 psi cut @ 8,600 psi 360°F cut @ 8,400 psi cut @ 8,600 psi 360°F
» RCT Toolstring.

Stuck Pipe Log

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» Radial Stuck Pipe Log Sample.


The stuck pipe log uses acoustic measurement techniques to provide a continuous record and evaluation of a stuck pipe string.
This logging service can be performed through drill pipe, casing, or tubing to identify problem areas.

Acoustic pulses, initiated at the instrument’s transmitter, travel through the pipe string and are measured at the receiver. The acoustic energy level at the receiver is proportional to the degree of stuck pipe. Similar to conventional cement bond log measurements, low attenuation readings indicate free pipe and high attenuation readings indicate stuck pipe.

The stuck pipe log is superior to a free point evaluation because the stuck pipe log is used to determine multiple stuck points throughout the well instead of only the first problem area. With a complete picture of the situation at hand, an informed decision can be made as to how best proceed in the pipe recovery operation, potentially saving many hours of time and money.

Kut Tool

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» KuTh Tool.

KuTh Tool

KuTh tools supply information about the mineralogy of formations. The most frequent sources of natural radiation in the formations are thorium, uranium and potassium; the gamma rays generated by different elements or elementary interactions have different energy levels. The spectral gamma ray kut tool can identify the source of a particular gamma ray by measuring their amplitude or energy level. This way the tool can identify the amount of potassium, thorium, and uranium present in the shales and sands.


• detailed stratigraphic correlation
• marker bed identification
• location of radioactive tracers
• identification of fractures and zones of high permeability
• identification of depositional environments


Length: 1.14 m (45”)
Detector Position: 0.39 m (14.40”) from the bottom
Diameter: 2-3/4″
Weight: 3.9 kg (8.7 lbs)
Pressure Rating: 70 MPa (10 000 psi)
Temperature Rating: 175°C (350°F)
Power: 55 VDC / 35 mA Single conductor cablehead
Output Signal: Positive pulses from the tool are separated from negative pulses on the line using anti-coincidence circuitry. Pulse polarity can be set according to user requirements.
Detector Type: He3 proportional neutron detector

Magnetic Thickness

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» Sample Casing Inspection Log.


The magnetic thickness tool is based on an electromagnetic phenomenon that can be observed by placing coils in a conductive pipe. The measurement is made with a coil arrangement that produces a magnetic field that opposes the primary field casing attenuation and phase shift.

The magnitude of the phase shift is a function of the casing electrical conductivity, magnetic permeability, and thickness of the metal present in the field. Defects in the pipe disrupt the eddy currents and are detected by the far field detector as increases in amplitude and shorter transit times. Multiple coil spacing and frequencies are used to control the depth of investigation and measure electromagnetic properties. The magnetic thickness tool measures casing wall thickness using a remote eddy current field measurement.

Phase shift of the signal received by the far field detector is proportional to wall thickness. A differential thickness measurement is made by a second receiver coil closely spaced to the far field detector. This provides an enhanced resolution of small defects in the casing wall.

An additional coil pair array provides an electromagnetic caliper which measures casing inner diameter. This measurement can be used in conjunction with a mechanical caliper to determine magnetic properties of an indicated defect.


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» WIP Survey Example.


A casing Inspection survey is further enhanced in a wellbore integrity presentation (WIP), combination casing n/bond log, using a radial bond tool (RBT) to log the cement bond around the casing.

WIP logs allow the engineer to make fully informed and accurate decisions based upon a more complete picture of the wellbore environment.

Please see the individual survey pages for information on the makeup of a WIP survey.

Injection Profiles

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Renegade Services Radioactive Tracer Survey

» Learn more about Radioactive Tracer Surveys and how Renegade Services can help you increase flood performance, renew your permits, and find your damaged pipe


Injection profiles are run to determine the health of injector units, monitor fluid dispersion, find and measure outofzone losses and provide a comprehensive picture of the overall downhole activity on an injection well.

Listed below are explanations of the common surveys used in the injection profile package. 


The radioactive tracer log determines injection flow profiles by monitoring the reduction in tracer material as it moves down the well. A slug of radioactive tracer is added to the injection fluid. As the slug moves down the well, several gamma ray logs are recorded at well-defined time intervals. 

The position of the slug is seen as a large gamma ray peak whose size is proportional to the flow rate. A reduction in the size of the peak indicates a loss of fluid into the formation. Fluid velocity can be calculated from the time interval and the distance the peak has moved using time-slug analysis. 

Radioactive tracer logs are used to determine injection flow profiles and detect channels or leaks. Tracer loss measurements are used mainly to give a general idea of fluid flow. 


A temperature log presents a record of the temperature gradient in a well. The temperature log is interpreted by looking for anomalies or departures from the reference gradient. Most anomalies are related to the entry of fluids into the borehole or fluid exit into the formation. 

Since the temperature is affected by material outside the casing, a temperature log is sensitive not only to the borehole but also the formation and the casing formation annulus. Temperature logs have many applications. The most common include identifying zones producing or taking fluid, evaluating a cement or hydraulic fracture treatment and locating lost circulation zones and casing leaks. 

Injection Profile Wireline Truck

» Our wireline and profile trucks are fully equipped, serviced regularly and made in the U.S.


A caliper log shows the measured diameter of the borehole along its depth. Since wellbores are usually irregular, it is important to have a tool that measures diameter at several different locations simultaneously. This tool is known as a multi-finger caliper. Drilling engineers use caliper measurement as a qualitative indication of both the condition of the wellbore and the degree to which the mud system has maintained hole stability. 

This information is crucial to all types of production logging. The actual internal diameter of a wellbore must be known in order for an accurate fluid rate to be calculated. 


A gamma ray log identifies total natural radioactivity, measured in American Petroleum Institute (API) units. The measurement can be made in both open hole and through casing. Shales and clays are responsible for most natural radioactivity, so the gamma ray log is often a good indicator for this type of rock. The log is also used for correlation between wells, for depth correlation between open and cased hole, and for depth correlation between logging runs.


Leaks present in any pipe string that you can pump into can be tested with this same process. These logs are often required by state regulations on disposal wells to ensure all injected fluid is leaving the well in the permitted zones and is not channeling up to higher intervals. Trial runs before pumping cement can also be performed to ensure abandonment procedures are met and cement locations are approved by state authorities.

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Digital Spectral Gamma Ray

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» Record of Spectral Gamma Ray 2017.



  • Length: 82.76″
  • Weight: 31 lbs.
  • Diameter: 1-11 /16″ & 2 3/4″
  • Measuring Point: 67.83″ from bottom
  • Connections: Single conductor/mono cable
  • Spectrometry: 256/512 energy channels
  • Communication: Digital 20 KHz, up to 2.7 times data frames per sec.
  • Data Frame: 267 words
  • Channels: 256 channels for spectrum in all working modes, time channel pulse indicator, cable head voltage, flask temperature, 2 counters channels, 1 A/D channel

Pulse pile-up capabilities: detectable, not correctable – presented as output on the log

Working Modes:

  • Mode 0 – sleep mode: auxiliary sensors works, gamma ray sensors
  • Switched off   HV on minimum;
  • Mode 1 – 256 energy channels spectrum presentation
  • Mode 2 – 512 energy channels spectrum presentation

Spectrum adjustment:

  • Gain command
  • LLD – low-level height discrimination
  • ULD – upper level of pulse height discrimination
  • Temperature range:
  • Without flask – 250 Degrees F – one hour

Casing Inspections

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» Sample Casing Inspection Log.


This page is dedicated to our Casing Inspection logging services. To see information about our combination casing inspection and radial cement bond log (Wellbore Integrity Presentation (WIP) Survey) Click Here.

A casing inspection log is a record of casing thickness and integrity. This log is used to determine whether or not the casing has undergone damage.

The casing inspection log identifies and quantifies corrosion damage. It identifies scale, wax, solids accumulation, and location of mechanical damage.

The multi-arm caliper (MAC) 60 is a state of the art, sophisticated logging tool that performs an accurate inspection of the casing interior. It is an integrated logging system enabling downhole data acquisition, high-speed data transmission to the surface, data processing, and vivid imaging of the inspected casing.

The data provided by the tool provides you with the knowledge necessary to plan cost-effective work-over and remedial operations.

This tool is designed with a small outside diameter with a large working range of measurement. The tool is capable of logging all weights of 4 1/2 inch through 10 3/4 inch casings. Each of the 60 arms sends an individual measurement to the surface. The actuation of each arm is converted to an electrical signal and transmitted above ground in a data frame consisting of a frame identifier, 60 arm channels, an electronics temperature data, and a checksum. The data is transmitted at a rate of 13 times per second. The surface equipment decodes the data frame and stores the data to disk.

The operator has the option of presenting the data in log form with various imaging presentations ranging from a cross-section of the casing to a 3-D type color enhanced visualization.

Radial Cement Bond Log

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» Cement Bond Log.


The radial cement bond tool (CBL) utilizes a single ceramic transmitter, an eight segment receiver at 3ft. spacing and a single receiver at 5ft. spacing to accurately measure the quality of the cement job in a cased hole well environment. The segmented receiver provides a good indication of cement channeling behind the casing.

This cement bond tool is of high-quality steel construction with oil filled, pressure compensated transmitter and receiver sections. The transmitter and both receivers are ceramic to withstand the hostile high temperature of well environments. Upon each transmitter firing, data from all the receivers is digitized and stored in internal memory, then sequentially transmitted to the surface computer.

The digital signal section is capable of transmitting data to the surface from tools run below the radial CBL such as gamma ray, casing collar log (CCL), in-line neutron, compensated neutron or other tool with one or two pulse channels running below the CBL tool.

Transmission of the sonic data to the surface is accomplished by an internal controller which transmits 8 signals from the radial receiver, a composite 3ft. signal (sum of all 8 radial signals), a 5ft. receiver signal, and an internally generated calibration signal. Transmission of the remaining signals consists of digitally encoded data transmitted after the acoustic signals.

The electronics contains firmware that allows the tool to be auto-calibrated inside a calibration fixture. The digital gain is set and all signals stored in memory. These signals can be transmitted uphole on demand by the operator.

Compensated Neutron Log

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» Compensated Neutron Log.


The dual detector compensated neutron log utilizes an Americium-241/Beryllium (AmBe) chemical source. Dual neutron detectors measure liquid filled porosity. Neutrons are primarily affected by hydrogen in the formation. With known corrections for the appropriate matrix (limestone, sand, or dolomite) a compensated neutron log is able to accurately determine porosity along with the presence of shale or gas behind the casing.

A compensated neutron log is useful for identifying zones of interest and determining perforating depths, tracking gas cap movement and gas encroachment under shale layers, as a correlation between open and cased hole where a gamma ray is not indicative, and to measure overall porosity of the well.

At Renegade we primarily use the compensated neutron log (CNL) to identify pay zones in a well. Once the zones of interest are identified and logged the engineer is able to make an informed decision about where and how they want to perforate the well.

Step Rate Tests

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Obtaining good data is the key to successful wellbore production. Testing step rates are one method for measuring this data, which can be very useful to identify the treatment parameters of the operation.

The process begins with measuring the bottom hole pressure. Once we know the conditions downhole, we sit stagnate for 30 minutes before taking a measurement. The results of that test allow us to provide accurate information that is pertinent in the design of a lift system appropriate to the site. When armed with that information, you can use the proper pressure and flow rate to complete your operation.

Renegade knows that useful data is at the heart of every successful job.

Memory Gauges

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An operational wellbore produces a tremendous volume of information that must be managed. A variety of diagnostic tools can help you manage your production functions and get a valuable insight into the processes that are occurring below the surface. They help operators to identify what systems they need to use and how to adapt to the conditions of the wellbore.

Memory gauges are one of the most helpful tools for diagnostics. They detect the pressure at the bottom of the hole and measure temperature. These gauges are also convenient because they provide more information without requiring a lot of resources and eliminate the need for e-line.  They are powered by a battery pack and can be set and left down-hole for an extended period to store data and then be retrieved at a later date.

The information allows operators to implement the right lift systems to get the oil/gas back out of the well and also provides the ability to determine the flow rate of the formation. When they know this information, they have better insight into how much fluid and pressure they are dealing with in a well. Having this knowledge saves time, money, and environmental damage.

A lot of companies provide this service, but only Renegade Wireline Services has the knowledge to ensure a successful job every time.

HAG® tool

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Renegade’s hydraulically actuated wireline grab is the latest game-changing device to be rolled out by the ever-evolving minds of Renegade Services.

HAG1℠ is the first device of its kind that uses a setting tool to collect the wireline in its jaws. Equipped with three hardened steel fingers that when ballistically initiated, grab the line through the stroking action of the setting tool with an unparalleled strength for a safe and successful retrieval of a wireline laden fish.

Unfortunately, the industry has seen a growing number of instances where the wrong valve is closed-in on wireline resulting in the loss of tools. As completions activity picks up, qualified and experienced personnel become stretched thin. When combined with the fast-paced routine of multi-well fracking, it has become evident that mistakes will happen.

For instance, a frac mistakenly shuts in the well that wireline is working in and cuts line at the surface. The HAG1℠ can be adapted to any setting tool and connects directly to the equipment that’s already on location. Now you can now restring, go right in and retrieve your line before a fishing service can even get mobilized. The time and money saved in this scenario outweighs the cost investment.

Before the development of Renegade’s HAG1℠, a mistake of this nature would have resulted in the expensive and time-consuming mobilization of coil-tubing to fish the tool.

Having HAG1℠ in-house now prepares you for the inevitable.

Pressure Control

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Pressure plays a crucial role in completing a well. You need the right equipment to make the entire system succeed, from lubricator assembly to the grease head. Pumping large volumes of fluid at high pressure always possesses the risk for loss of well control. Having properly maintained equipment run by competent operators is Renegade Services recipe for success.

Oil well blowouts are easily the most catastrophic incident that can occur on a rig site. A blowout causes significant damage to the environment, creates a loss of resources, and significantly increases the risk of injury or even death to rig workers. Blowouts also cause lost production time and a major negative financial impact. Therefore, proper control of the amount of pressure within the system is more than just an excellent idea; it’s an essential part of managing potential hazards.

Proper control measures maintain safe working conditions on location. The tool string is placed inside of the lubricator and is then attached to the well. When secured, and the proper seal is verified, the valve leading into the well is opened. Thus allowing thousands of pounds of pressure to enter the lubricator. When done correctly, it will enable the pressure to move into the lubricator and around the tool string without releasing it into the atmosphere.

Most companies hire third-party operators to manage this process. The more outside contractors that have to be brought in, the less efficient the process becomes and the more risk the company faces. Renegade Services provides its own highly trained staff to run PCE on its completions projects. This offers significant peace of mind that you’re both reducing risk and protecting valuable resources.

Renegade uses the RigLock® system in completion projects to attach and detach the nightcap and wireline lubricator remotely to maintain exceptional safety practices on the frac pad. Since there’s no technician needed in the red zone when using RigLock®, frac operations can continue interruption free speeding well completion time resulting in increased well profits. Using the RigLock® revolutionary technology for wireline operations resulted in record-breaking frac pad production and significantly decreases workers’ safety risk.

Renegade also provides PCE recertification service through our iron recertification district. Services that we provide to our customers include visual thickness, hydrostatic and magnetic particle testing. We complete annual inspections of the equipment that we use on location. Up to date records and proof of certification are essential requirements that must be met to comply with most of our customer’s expectations.

Renegade understands that every well is different and chooses the best equipment for functionality and safety, which prevents dangerous and costly loss of well control. Renegade manages it all for you, from crane rigging to running guns and handling PCE. No third parties needed and all our equipment is made in the USA.

Greaseless Line

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» During traditional wireline operation, the line is subject to contact with multiple segments of casing, collars and wipers. Each touch point increases the friction applied to the line. Because it does not use collars, wipers and tubes, greaseless line drastically reduces friction and tension resulting in lower line tensions during pump-down operations.

renegade services no mess HSE icon


During conventional wireline operations the grease that’s pumped into the grease head tends to be spread across location. This creates a greater environmental impact on the site, which either leaves a big mess behind or presents the need to be cleaned up. Communities are increasingly concerned about the environmental impact of drilling and don’t understand the real issues involved. Grease easily slings off of sheave wheels and hangs in the air, creating a major problem everywhere. In many ways, it’s one of the biggest hassles on a frac site.

Choosing the right line to run is more important than some may realize. The conventional line has two sets of outer armor wires with a conductor in the middle, but requires a grease injection head to seal the line. It’s messy, inefficient, and not the most environmentally-friendly solution.

Fortunately, this is a headache that’s preventable. Renegade Services uses Streamline® greaseless line, which has been used successfully on thousands runs. Renegade was one of the first to implement it in 2014 and brings years of expertise in its use to every job.

Greaseless line is the best choice for many reasons. Along with the two sets of armor wires around a conductor, the greaseless line is also coated with a non-stick chemical, which eliminates the need for supplemental grease. Even though it has a greater upfront cost, it saves money in the end because there isn’t the additional need to pump in grease to seal conventional lines, and because it is also an environmentally-friendly alternative and there is no clean-up required. This is an increasingly important issue on today’s completions sites.

Count on the experience & efficiency of the right environmentally friendly line for the job. Eliminate the mess from traditional wireline grease and eliminate the need for costly wellsite cleanup when you choose Renegade Services.

» Streamline® Greaseless Line

Renegade has Plug and Perf specialists in every region of the U.S.

Call us today for a live presentation and equipment consultation.

Addressable Perforating Software

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Digital technology meets the completions industry. The latest software guides the perforating process with the help of computer precision. The old way of conducting this process was to use a traditional blasting cap, which allowed the operator to push a series of buttons and send a signal down the line, initiating the explosive sequence. However, the old way of using traditional blasting caps had the disadvantage of being subject to human error. This was particularly because explosives were involved—mistakes could be critically dangerous and costly. The newer system of perforating is much more precise, organized, and pre-planned.

The new Addressable Perforating System assigns a unique IP address to each individual detonator. It is then programmed to go off with a certain command and cannot accidentally be detonated until it receives its own unique, pre-determined code. DynaEnergetics is working in partnership with Renegade to offer this technology in the advanced perforating environment. The system is closed, meaning that the DynaEnergetics equipment can only be used with Dyna style components. Other perforating must be done with a completely separate panel.

One of the other big benefits the DynaEnergetics addressable system offers is that it can also be used for other purposes. Each tool can be assigned a code using this technology, from the release tool to through gun string and ending up at the setting tool in the gun string. It also allows the opportunity to skip over specific guns if a misfire occurs. This provides more specificity and control. In turn, this reduces the overall wireline mis-run rate.

Crane Services

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» Integrated crane and wireline services on a zipper pad in the Permian Basin.



Successful wireline operations depend on many variables, but foremost is a well-trained and organized crew and the right equipment. Moving and lifting equipment while rigging up and rigging down is a critical part of wellsite operations and one of the most demanding. Bringing in a third-party operator to handle this operation can lead to miscommunication, mistakes and even possible injury. Plus, the added burden of paperwork and project managing the vendor can quickly add costs to the operation. 

Renegade Wireline Services provide a full range of cranes for wellsite support. Along with this comes the knowledge, experience and safety methods that only thoroughly trained personnel can provide.  

Permian Basin 30-55 TON  
Northeast 50-110 TON  
Gulf 40-50 TON  
Rockies 30-50 TON  


Renegade crane equipment and personnel directly support wireline operations by suspending the lubricator assembly and BHA over the well. The operator is responsible for rigging up the frac iron before the job starts and again when it is finished. This equipment is also used to hoist or move heavy equipment, as well as picking up gear such as coil tubing injector heads. Larger well pads require cranes with a longer reach, so larger capacity cranes are used in these circumstances.  

While the lifting capacity of cranes can vary, the correct size is selected based on how heavy the equipment is and how far away it must be handled. Most cranes operated by Renegade have 50-ton and 110-ton capacity and a variety of operating ranges.    

Bringing in a third-party crew can be both expensive and less efficient. Crew members who work together daily can anticipate challenges that arise during completion operations and remedy them with the best solution. The primary advantage of Renegade Services providing wellsite crane operations is one integrated team at the wellsite familiar with and sharing common best practices, lessons learned, and safety procedures.

Why risk your operation to anyone else?

» 110 ton crane operating on a coil-tubing project in the Northeast US.

 Ask your sales rep to ADD crane services to your wireline package today

Call us today for a personalized service estimate.

Art Tool

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» Art tool diagram.

Art Tool

The ART-H is intended for use in horizontal and highly deviated wells in conjunction with down-hole tractor devices where the controllable release of all or part of a stuck tool-string is required. The tool can replace the able weak point, thereby improving operational safety, or be used to release a specific section of a tool string below a tractor, such as a partially set plug or expanded gun string.

The tool is specifically intended for use above a down-hole tractor, but can also be deployed below. The tool can also be deployed with electric-line equipped coiled tubing.

The ART-H is designed to withstand the high voltages used to drive down-hole tractors and is able to carry a maximum safe working load of three tonnes and a fishing load (post-release) of ten tonnes. A number of fail-safe mechanisms are incorporated into the device to ensure safe and reliable operation. These include encoded data transmission and validation of user-selectable code, a minimum well pressure for activation and non-operation in the event of a seal failure.

Up to seven ART’s can be run in a single tool-string, including mixed -H, -A and -B types.

Once released, a fishing neck remains to facilitate further recovery operations, with both upper and lower heads being pressure isolated to prevent entry of well fluids. Until release, the entire tool is pressure sealed, thereby minimizing maintenance and service time.

The ART-H is available with interfaces to suit most tractor/logging tool combinations in use.



• Release of Stuck Down-hole Tractors
• Release of Partially Set Plugs/Packers
• Release of Damaged Gun Strings
• Release of Stuck Logging Tools

Head Tension Service

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Head tension service offers real-time views of tool string activity.

Today’s highly commoditized NAM frac industrial drilling rigs are being pushed to finish wells faster, which often leads to the wellbore not being as straight and precise as necessary. This directly affects pump down operations by introducing severe doglegs and toe up conditions. Successful plug and perf operations require that the gun string to be run in and out of the well in rapid succession with as little restriction as possible. These undesirable conditions can complicate the process of successfully reaching a target depth, or for that matter, pulling the tool string back to surface from that depth. It can be difficult to see the forces being applied to the tool while traversing these unique wells. Tools can easily be lost during the pumping process, which can increase the time and cost of completion.

Wireline operators closely monitor the tension being applied to their BHA by a weight indicator. The weight indicator is a standard device used to measure the tension on the wireline but often cannot detect problems until it’s too late. Monitoring weight at surface alone is not sufficient. Pumping operations and downhole conditions can alter the accuracy of the weight indicator. This inaccurate data means tools can’t be fully monitored and problems cannot be foreseen.

The head tension tool provides accurate insight into pump down operations and offers a real-time advantage over weight indicators.

TCP – Tubing Conveyed Perforating

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Renegade Services TCP guns fired


Our operators were trained by the BEST IN THE INDUSTRY, true INNOVATORS within tcp. With over 20 years of operational experience, OUR engineers and field crews are experts on the full system capability of this effective and versatile service.

TCP OPERATIONS ARE offered from all of our field locations, based in oil and gas plays around the country. our mobile service operates out of the aRKLATEX AREA, prepared to quickly deploy to any location across the US. 

Become a customer for life. Work with the best.

When is TCP most effective?

Horizontal & Highly deviated wells

The innovative TCP process allows our operators to service horizontal and highly deviated wells where traditional wireline is limited.

Complete sterile zones 

TCP can be used in underbalanced situations when fluid sensitive zones are being perforated. Using TCP, the lower zones can be produced after the upper zones.

Start producing right after perforating 

TCP is designed so the well produces directly after shooting. Unlike traditional wireline, TCP allows the well to flow right after the gun is fired (perforating). 


Renegade Services Pipe recovery – fracing

Renegade TCP Service Overview 

  • Horizontal & Vertical Wells 
  • Under- and Overbalanced Wells 
  • Dropping Gun Systems for Straight Hole Wells 
  • Shooting Multiple Stages
  • Pipe Recovery
  • Re-Fracs with Pulse Wave System 
  • Capability to Shoot Stim Sleeves 
  • Industry Leading Firing Systems
  • Strategic Gun Modeling with Charge Manufacturers 

Firing Systems (impact detonation) 

  • Mechanical Bar drop
  • Ball Drop
  • Direct Pressure
  • Auto Release
  • Extreme over Balance

TCP Applications



Tubing Conveyed Perforating is deployed on coiled tubing. Renegade has the capability to convey guns on horizontal and vertical wells regardless of pressure in the wellbore.


TCP guns are run below a permanent or retrievable packer with a wireline unit to log and control depth. The TCP assembly is positioned by setting the packer prior to dropping the bar and pressuring the wellbore.


Customers are surprised to learn that re-fracs can be done easily utilizing Pulse Wave System from Renegade, which reduces the number of tools run into the wellbore, and can be performed with just a single trip in the well.


TCP can be used in conjunction with DST tools for exploration and reservoir evaluation. With the rise in horizontal drilling, TCP operations have shifted to pipe recovery operations. However, Renegade is still able to utilize TCP for quick and accurate exploration and reservoir evaluation. 


TCP on a stick pipe off rig with renegade services

Renegade has the ability to use TCP when rigs requiring longer gun intervals are required in permanent completion scenarios.

EXPERTISE & AVAILABILITY – Experience the Renegade Difference Today

Call us today for a live presentation or consultation.

The Annual AESC Award

Every year, the Association of Energy Service Companies (AESC) awards a Gold, Silver, or Bronze award to energy companies with a high level of safety standards. Participating companies contribute to the overall understanding of safety statistics by volunteering their safety data. As a contributor for the past few years, Renegade has presented their information because they are deeply committed to the highest level of safety.

How the AESC Award Works

Each year, the AESC award is determined by three factors. First, each participating company is categorized as either Well Servicing/Workover Rig or a Non-Well Servicing Rig Category. Second, the companies are then divided into groups depending on the number of hours that they reported. Finally, they award either Gold, Silver, or Bronze for each Group.

Reported Hours Groups

The group determination by hours is key to recognizing the high standards of energy service companies of various sizes. The groups are determined as follows:

Total Recordable Incident Rate

Within each group, the AESC award is determined by the Total Recordable Incident Rate (TRIR) of each company. The participant with the lowest TRIR in a group receives the Gold, followed by the second lowest receiving the Silver, and the third lowest receiving the Bronze. The high standard for safety and a low number of incidents of every participating company is key to AESC’s mission for industry safety.

Renegade’s Record of Safety

At Renegade, the commitment to safety is paramount. As a participant in AESC safety reporting, Renegade received the Silver Award in the Non-Well Servicing Rig in Group 4 in 2016. In the following year, Renegade’s continued work towards high safety standard was awarded a 2017 Gold in the same category and grouping.

Overall, as a wireline company in the energy industry, Renegade understands the importance of high safety standards and low incidents. By receiving the AESC awards in both 2016 and 2017, it is clear that a high level of safety is deeply important to Renegade as a whole.

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