SWAT Spectral Well Analysis

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» Record of Spectral Well Analysis.

SWAT SPECTRAL WELL ANALYSIS

SPECTRAL GAMMA RAY

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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NO WASH ISO SEAL

“NO WASH” PRODUCT

(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.

FEATURES OF ISOSEAL-3 “NO WASH” MATERIAL:

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

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

ABSTRACT

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

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

ABSTRACT

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

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

ABSTRACT

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 IMPROVE HYDRAULIC FRACTURING

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

ABSTRACT

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

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

ABSTRACT

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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TRACERS FACILITATE STIMULATION JOB EVALUATION

ABSTRACT

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

ABSTRACT

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

CIRCULATING PYRO TORCH

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.

BENEFITS

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

OPERATION

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.

CPT’S ARE AVAILABLE FOR:

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

SUPPORT TOOLS

GENERATOR SAFETY SLEEVE® (GSS)

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

REMOTE FIRING MECHANISM® (RFM)

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

Radial Cutting Torch

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RADIAL CUTTING TORCH

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.

OPERATION

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).

RCT’S ARE AVAILABLE FOR:

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

SUPPORT TOOLS

ELECTROMECHANICAL ANCHOR® (EMA)

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

GENERATOR SAFETY SLEEVE® (GSS)

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

REMOTE FIRING MECHANISM® (RFM)

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

CUTS MADE WITH THE RCT

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.

STUCK PIPE LOG

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.

APPLICATION

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

TECHNICAL SPECIFICATIONS

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 V_DC/ 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.

MAGNETIC THICKNESS

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.

WIP LOG

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» WIP Survey Example.

WIP LOG

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

Injection profiles are run to determine the health of injector units, monitor fluid dispersion, find and measure out–of–zone 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.

RADIOACTIVE TRACER LOG

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.

TEMPERATURE LOG

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.

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

CALIPER LOG

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.

GAMMA RAY LOG

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. 

OTHER APPLICATIONS

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.

Digital Spectral Gamma Ray

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» Record of Spectral Gamma Ray 2017.

DIGITAL SPECTRAL GAMMA RAY

Specifications:

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.

CASING INSPECTIONS

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.

RADIAL 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.

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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TRUST RENEGADE TO PERFORM STEP RATE TESTS

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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MEASURE AND ADAPT TO WELLBORE CONDITIONS WITH MEMORY GAUGES.

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.

Fishing

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RENEGADE GOES THE EXTRA MILE IN FISHING

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.

HAG® tool

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RENEGADE’S HAG1℠ EFISHING℠ TOOL MORE COST EFFECTIVE THAN COIL TUBING

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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MINIMIZE RISK AND MAXIMIZE EFFICIENCY WITH RENEGADE PRESSURE CONTROL EQUIPMENT (PCE).

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 USES GREASELESS LINE FOR Environmentally-FRIENDLY SUCCESS

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

Addressable Perforating Software

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ADDRESSABLE PERFORATING SOFTWARE USES TECHNOLOGY TO REMOVE HUMAN ERROR

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.

INTEGRATING CRANE SERVICES WITH WIRELINE OPERATIONS PROVIDE EFFICIENCY AND COST-SAVINGS TO THE OPERATOR

CRANE SERVICES FROM RENEGADE ENHANCE WIRELINE OPERATIONS

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.

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.

Applications

• 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 – Experts IN TUBING CONVEYED PERFORATING (TCP)

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

COIL TUBING

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.

WIRELINE

renegadewls-truck-onsite-grunge-setting-square

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.

REFRACS

$refrac-Perforating$

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.

LAND RIG

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.

WORKOVER

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.

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:

Group 1 reports 0 – 75,000 hours
Group 2 reports 75,001 – 150,000 hours
Group 3 reports 150,001 – 300,000 hours
Group 4 reports 300,001 – 2,500,000 hours
Group 5 reports anything greater than 2,500,001 hours

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.

Renegade Plug & Perf Services: A Better Experience

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

RECIPE FOR SUCCESS

PRE JOB

JOB

POST JOB

COMMITMENT TO SAFETY

Streamline® Greaseless Line

IDC TOOL

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

DOWNHOLE INSIGHT™

DOWNHOLE INSIGHT™

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

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

Now available from ReneGade Services

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

FEATURES

Case StudIES

THE DOWNHOLE INSIGHT™ NuWavTM CAMERA IS ONLY AVAILABLE FROM RENEGADE SERVICES

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

Gas Migration

MAN-MADE “PERMEABILITY”

TOOLS

CET – Casing Expander Tool™

What is the award for?

The Award Categories

Renegade Wins the Award

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

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

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.

Get Better Real-Time Information with eLine.

A few examples of our eLine tools include:

STUCK PIPE LOG

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

Remove the person from the risk.

RIGLOCK CONTROL UNIT

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

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.

The Future of RigLock® Innovation

“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

RigLock® 15K Features:

RigLock® 15K Control Unit Features:

A RigLock® is Ready for You

IDC Tool

APPLICATIONS

24/7 CONVEYANCE SOLUTIONS FROM RENEGADE FOR EVERY APPLICATION

The Service Company You Hire Matters

SWAT SPECTRAL WELL ANALYSIS

SPECTRAL GAMMA RAY

Isotopes Commonly Used for Tagging

NO WASH ISO SEAL

“NO WASH” PRODUCT

FEATURES OF ISOSEAL-3 “NO WASH” MATERIAL:

RADIOACTIVE TRACERS OFFER A CLOSER LOOK AT HORIZONTAL COMPLETIONS

ABSTRACT

THE DETERMINATION OF FRACTURE ORIENTATION USING A DIRECTIONAL GAMMA RAY TOOL

THE DOWNHOLE INSIGHT™ NuWav^TM CAMERA IS ONLY AVAILABLE FROM RENEGADE SERVICES