bluuebunny/crossref_metadata_2025_split huggingface dataset:
Reducing Operational Time, Fluid Usage, Hydraulic Horsepower, Risk, and Downtime: Targeted Fracs Using CT-Enabled Frac Sleeves
Authors: Castro Luis , Watkins Thomas , Bedore Brian , Holt Robert , Manuel Greg 
Published: March 2012

Abstract
Unconventional reservoirs are an increasingly important part of the hydrocarbon production pool in North America. Since reservoir conditions typically mandate the use of hydraulic fracturing for economical production results, a significant amount of resources are focused on making the fracturing process faster, more efficient and lower its environmental impact.
This operational review focuses on a novel technique to rapidly perform targeted annular hydraulic fractures by deploying an activation tool on coiled tubing (CT) to open frac sleeves in a horizontal well. The paper covers results from the first operation of its kind in the United States – where a total of 48 stages were fractured in approximately 100 hours of operational time.
The new technology does not involve dropping balls or setting composite plugs to isolate stages. Rather, the technique utilizes frac sleeves that are swiftly activated using a CT bottomhole assembly. The sleeves can be cemented in place if desired and have a full-bore internal diameter that does not require post-treatment composite plug millouts, further reducing overall completion time and efficiency.
The operator preferred this method due to its targeted nature, efficiency and potential fluid savings. As opposed to multi- cluster fracturing methods (such as ‘plug-and-perf"), a single entry point during the frac job promotes increased fluid velocity, allowing for a more aggressive sand ramp and reduced required hydraulic horsepower. Similarly, the single entry point ensures that a fracture is generated at each port, as opposed to the possibility that some clusters are not treated. In addition, since no composite plugs or diverting devices are required to be pumped down the wellbore, water usage is reduced considerably. The system, already used in thousands of fracturing stages in Canada, speeds up the completion process, uses less fluid, minimizes risks, and reduces overall downtime.
Milling of an Electric-Line Obstruction With Electric Line Conveyed Technology
Authors: Dulic A. , McIninch B. , Mullin M. 
Published: March 2012

Abstract
A new application of electric wireline tractors in combination with the well milling technology has been successfully proven in an offshore Equatorial Guinea well.
In July 2011 on a small, unmanned offshore platform in Equatorial Guinea, a downhole tractor and a milling tool were conveyed on electric line to remove an obstruction created by Lost in Hole (LIH) electric line cable and production logging tools (PLT).
By using customized core milling bits, 13 successful milling runs were made. During this unique operation, most of the milled wireline material was recovered, and the challenges of controlling torque and milling penetration were achieved. In between milling runs, slickline fishing attempts were made in order to recover the remaining LIH wireline. After the last milling run, a major breakthrough was made when the PLT string moved downhole to a position that uncovered the proposed new completion interval. Ultimately the well was perforated and returned to production at projected gas and condensate rates.
Milling of wireline and other well bore obstructions on electric line offers a cost efficient alternative technology to existing methods. Furthermore, it offers reduced Health, Environment and Safety (HES) risk benefits and logistical advantages.
This paper will describe the actual process from preparation to completion of this first-of-its-kind fishing operation.
High-Angle Gas Lift Valve Removal and Replacement in a Single Run
Authors: Chow Hayes , Herrmann Daniel , Condio John , Albright Jeremy , Burley Leighton , Greenlee James 
Published: March 2012

Abstract
An operator in Prudhoe Bay, Alaska required the ability to replace gas lift valves in their completion for improved oil production. Conventional methods had reached their limits due to extended well lengths and high-angle well deviations. Slickline was unable to overcome the higher deviations, while imprecise depth control during coiled tubing operations required multiple run-in-hole attempts to pull and replace the valve.
Based on previous, positive experiences with electric line - mechanical solutions, the customer chose a unique solution using a newly modified Kick-Over Tool (KOT). Two KOTs run in tandem and combined with a tractor and a hydraulic stroking tool (HST) were used to pull the existing gas lift valve (GLV) and replace it in a single run. The tractor conveyed the tool string to the correct depth where the HST and the first KOT provided the pulling force for removal. Then, the HST and second KOT were used to successfully install the new GLV into the mandrel.
The operator is now able to optimize their gas lift design without the limitations imposed by conventional means for installing GLVs such as slickline and coiled tubing. This allows them to place gas lift valves in the high angle sections when necessary for increased oil recovery from their reservoirs.
Few changes have been made to the Kick-Over Tool technology in the past 40 years but it has been recently improved to operate more reliably in deviated and horizontal wells and has been modified to accommodate the forces generated by the HST. This paper will describe the challenges with the planning and execution of this operation and the implications for future gas lift design.
Slickline-Conveyed Electromechanical Tool Utilization in Deepwater Gulf of Mexico
Authors: Gary B. , Schlechtweg J. , Clemens J. , Garrett J. 
Published: March 2012

Abstract
Traditional slickline work usually encompasses basic mechanical manipulation for downhole intervention work. In the recent past, a variety of battery-powered downhole tools have emerged in the market, providing additional deepwater solutions for the industry. These tools include the extended-reach downhole power unit and the smart release tool. The downhole electrical power unit is an electro-mechanical setting tool that uses a timer activation switch to begin the setting process for a variety of downhole tools. The smart release tool provides a timer-based mechanism to release the deployment wire from the downhole toolstring, eliminating the exposures associated with dropping a cutter in the event of a stuck tool. These tools can be conveyed on slickline for a variety of intervention solutions, including setting tubing plugs and packers, pulling subsea tree plugs, setting pressure gauges in tubing profiles, and providing a mechanical release in highly-deviated, extended-reach wellbores.
This paper discusses specific well-intervention case histories using the downhole electrical power unit and the smart release tool. In the first case history, the downhole electrical power unit was used to set a packer assembly during a safety- valve repair. The smart release tool was used to soft set memory pressure gauges in wells without functioning, permanent downhole gauges, eliminating the need for jar action that could damage the gauges. Adaptations were made to the existing tool designs to respond to the well-specific challenges.
These case histories demonstrate applications in which the electro-mechanical timer-activated tools have provided solutions for deepwater Gulf of Mexico well-intervention projects. The discussion includes lessons learned from previous project designs, development of operational best practices, and possible future applications to extend the role of slickline in deepwater operations. Applications may include the use of the downhole power unit to set packers and bridge plugs in conjunction with memory logging tools to correlate depth, as well as continued use of the smart release tool to minimize risks associated with downhole mechanical evaluation and memory data acquisition.
Use of Coiled Tubing Deployed Expandable Technology in Sidetrack Drilling Operations
Authors: Caccialupi A. , Benzie S. , Filippov G. 
Published: March 2012

Abstract
During sidetracking operations in re-entry wells, unstable formations significantly reduce the probability of success. A typical solution to mitigate the problem is to set conventional casing across the trouble zone. The casing would serve as a mechanical barrier to prevent the collapse of the borehole.
In many cases, the tubing or casing used for re-entry operations is small diameter, e.g., 4-1/2". Due to the small diameter, limited equipment is currently available for completion of these wells. Furthermore, due to the limited size of the production conduit after completing the re-entry with conventional equipment, the well becomes uneconomical.
As a solution to the limitations of conventional casing, solid expandable casing has been identified as a viable option to enable the completion of such directional wells. This technology provides mechanical stability in situations where conventional casing strings cannot be installed in the well due to geometrical restrictions.
The geometrical restrictions encountered in these re-entry wells coupled with the relatively large drift diameter needed to effectively complete the pay zone, calls for an expandable system with relatively large expansion ratios up to 30%. These high expansion ratios constitute a technological step-out with respect to off-the-shelf expandable systems.
Due to basic system limitations, these high expansion ratios cannot be achieved with hydraulic expansion systems. Therefore, a mechanical system which transmits no internal pressure to the expandable pipe during expansion is the most suitable solution.
First Successful HP/HT Coiled Tubing Milling Job in the Norwegian Continental Shelf Deployed With Telemetry: Kvitebjoern Case Study and Lessons Learned
Authors: Ridene Mohamed , Stragiotti Stephen , Holst Tor Kristian , Baardsen Johnny , Effiong Godwin 
Published: March 2012

Abstract
Kvitebjoern is a Statoil operated gas and condensate field that lies in block 34/11 in the Norwegian North Sea. The reservoir lies about 4,000 meters down, and features high pressure and temperature conditions (770 bar and 160 deg C).
34/11-A-9 T2 well was drilled as a gas producer by end of October 2009 and completed in February 2010. During the final completion phase, it was not possible to open the High Pressure/High Temperature (HP/HT) isolation ball valve set in the 9 7/8" liner at 6245.7 m MD / 3795.8 m TVD through pressure cycling.
After several failed attempts to open the isolation ball valve with wireline using mechanical override tools, it was decided to punch above it to allow well production passing the outside of the valve through the annulus between 9 7/8" liner and the 5 ½" tail pipe. However, the production performance was poor. A feasibility study was carried out to evaluate available methods for opening or milling out the valve with the objective to improve the production characteristics. Thewell is an exploration well and an important objective for the operation was also to allow access forfuture production logging tools.
The decision was then taken to mill the stuck-closed isolation ball valve using Coiled Tubing (CT).
The operation presented several critical challenges. Statoil had not performed any HP/HT CT operations and the available experience was limited.
To minimize uncertainty relating to depth determination during the milling operation, it was decided to use a telemetry system run at its operational pressure and temperature limits to provide real time Casing Collar Locator (CCL) reading in addition to downhole pressure and temperature data.
The paper covers the detailed planning phase for this first successful HP/HT CT milling job in theNorwegian Continental Shelf including experience with use of telemetry system. It illustrates the relevant well and reservoir data, operational steps, well control stack up configuration, operational risk analysis and lessons learned during the job execution leading up to successfully milling out the isolation ball valve with a 4" dome mill.
Slickline DTS Measurements Provide Useful Information for Well Integrity Diagnostic, Stimulation Treatments, and Water Injector Wells Performance: North America Land Case Studies
Authors: Gonzalez Y. J. , Brown G. A , Friese A. , Padilla A. , Sanchez A. , Ward L. 
Published: March 2012

Abstract
Distributed Temperature Measurements (DTS) have been used in the oilfield now for over 10 years, with the majority of applications requiring the fiber to be installed permanently in the well, either inside a 1/4-in control line or as part of an electrical gauge cable. A slickline 1/8-in diameter wire has now been developed with an optical fiber embedded inside it so that DTS measurements can be performed during a conventional slickline operation.
This new approach to temperature monitoring means that the optical fiber can now be deployed temporarily in a producer or injector well only when needed, using a conventional slickline unit which can also run a bottomhole pressure gauge or a production log at the same time. The ability to monitor the whole well with DTS using a slickline intervention installation allows the operator to use this technology to resolve a range of well integrity, production and stimulation problems.
This paper highlights the use of fiber-optic slickline monitoring in Texas and New Mexico over the past two years by discussing a number of field cases that show the application of this technology for monitoring well integrity and diagnosing well problems, how the DTS can be used to evaluate the fracture height created by a fracture job, determining the effectiveness of the stimulation in acid stimulation operations and also how the data can be used to monitor water injection in low rate injector wells.
Because the fiber is deployed and data is acquired on a "when needed" basis, it is proving much more economical than a permanently installed optical fiber, and can bring the benefits of this monitoring technology to a greater number of wells.
Using Coiled Tubing as Sucker Rods for SRP
Authors: Flores-avila F. S. , Riano J. M. , Javier-Martinez M. , Hammond T. , Cantu J. , Ramos J. 
Published: March 2012

Abstract
Sucker rod Pumping (SRP) has been among the most efficient artificial lift systems. This method has proven to be one of the most popular ones while having some modifications in the prime mover systems, using hydraulic, pneumatic or mechanical devices. However, one of the most frequently encountered problems with this system is that while the well is being produced, sand is dragged from the formation to the well. Whether it comes from the fracture (propant) or the formation itself, this interferes with the pumping system and the fluid flow to the surface.
In SRP, fluid flow velocity is not enough to maintain sand suspended so that it could be brought up to the surface, ending up precipitated and being deposited on top of the pump causing a reduction in efficiency and premature wear of the pump components, if not stocking the pump at all.
Due to this effect, the well must be scheduled for work over in order to remove the sand. This implies to move and de-move a work over rig which can take several days with the associated cost and deferred production.
Using Coiled Tubing instead of a sucker rod string, maintenance can be achieved to the well through pumping and circulating fluids without having to remove the string and bottom hole pump, taking just about a couple of hours to perform the job.
Production can be restored in few hours, reducing down time, maximizing well production. It also can be used in a preventive mode by pumping chemicals that will help fluid flow by preventing scale build up and viscosity reduction in the case of heavy and viscous crude oils.
Coiled tubing string is designed to fit specific needs such as depth, pressure, and loads expected during the operation. It may vary in diameter, wall thickness, and stiffness. This paper describes the first time application in México for this technology which offers a great potential in mature fields. It also describes coiled tubing design criteria as well as string evaluation after the trial test performed.
Comparison of the analgesic efficacy of oral ABT-116 administration with that of transmucosal buprenorphine administration in dogs
Authors: Niyom Sirirat , Mama Khursheed R. , De Rezende Marlis L. 
Published: March 2012

Abstract
Objective—To evaluate the analgesic efficacy of ABT-116, a transient receptor potential cation channel vanilloid subfamily V member 1 antagonist, and compare it with that of buprenorphine by measurement of mechanical and thermal nociceptive thresholds in dogs.
Animals—Six 7- to 8-month-old dogs (3 males and 3 females).
Procedures—In a crossover study design, all dogs received ABT-116 (30 mg/kg, PO) and buprenorphine (0.03 mg/kg, orotransmucosally), with each treatment separated by 1 week. Physiologic variables were recorded prior to and 1, 6, and 24 hours after drug administration. Thermal (thoracic) and mechanical (dorsolateral aspect of the radius [proximal] and dorsopalmar aspect of the forefoot [distal]) nociceptive thresholds were assessed prior to (baseline) and 15 minutes and 1, 2, 4, 6, 12, 18, and 24 hours after treatment.
Results—Buprenorphine administration resulted in higher overall thermal and proximal mechanical nociceptive thresholds, compared with ABT-116. Distal mechanical nociceptive thresholds after treatment were higher than baseline values for both treatments, but the magnitude of change was greater for buprenorphine at 1 hour after administration. Whereas HR and RR sporadically differed from baseline values after ABT-116 administration, rectal temperature increased from a baseline value of 39 ± 0.2°C (mean ± SD) to a peak of 40.6 ± 0.2°C at 6 hours.
Conclusions and Clinical Relevance—In dogs without inflammation or nerve injury, PO administration of ABT-116 did not consistently result in an increase in nociceptive thresholds. However, clinically relevant increases in rectal temperature were identified after ABT-116 administration.
Effect of kennel noise on hearing in dogs
Authors: Scheifele Peter , Martin Doug , Clark John Greer , Kemper Debra , Wells Jennifer 
Published: March 2012

Abstract
Objective—To evaluate the degree of noise to which kenneled dogs were exposed in 2 typical kennels and to determine whether a measurable change in hearing might have developed as a result of exposure to this noise.
Animals—14 dogs temporarily housed in 2 kennel environments.
Procedures—Noise levels were measured for a 6-month period in one environment (veterinary technical college kennel) and for 3 months in another (animal shelter). Auditory brainstem response testing was performed on dogs in the veterinary kennel 48 hours and 3 and 6 months after arrival. Temporal changes in the lowest detectable response levels for wave V were analyzed.
Results—Acoustic analysis of the kennel environments revealed equivalent sound level values ranging between 100 and 108 dB sound pressure level for the 2 kennels. At the end of 6 months, all 14 dogs that underwent hearing tests had a measured change in hearing.
Conclusions and Clinical Relevance—Results of the noise assessments indicated levels that are damaging to the human auditory system. Such levels could be considered dangerous for kenneled dogs as well, particularly given the demonstrated hearing loss in dogs housed in the veterinary kennel for a prolonged period. Noise abatement strategies should be a standard part of kennel design and operation when such kennels are intended for long-term housing of dogs.
Clinical, behavioral, and pulmonary changes in calves following inoculation with Mycoplasma bovis
Authors: White Brad J. , Anderson David E. , Renter David G. , Larson Robert L. , Mosier Derek A. , Kelly Lindsey L. , Theurer Miles E. , Robért Brad D. , Walz Michelle L. 
Published: March 2012

Abstract
Objective—To characterize clinical and behavioral changes in calves following inoculation with Mycoplasma bovis and evaluate relationships between those changes and pulmonary disease.
Animals—22 healthy Holstein steers.
Procedures—20 calves were inoculated intranasally with < 108 CFU or > 109 CFU of M bovis. Calves were assigned a clinical illness score (CIS) on a scale of 1 through 4 twice daily on the basis of severity of cough, labored breathing, and lethargy. For each calf, distance traveled and time spent near the waterer, feed bunk, or shelter were determined via a remote location monitoring device. Calves were euthanized and necropsied 22 days after inoculation.
Results—13 calves became clinically ill after challenge inoculation; 3 calves were euthanized within 20 days. Among all calves, consolidation was evident in 0% to 79.9% of the lungs; extent of lung consolidation did not differ between the challenge dose groups. Distance traveled and percentages of time spent in proximity to the feed bunk and shelter were associated with CIS; calves with more severe disease traveled less distance and spent less time at the feed bunk and more time in the shelter. Distance traveled by calves was negatively associated with extent of lung consolidation (< or ≥ 10% of lungs affected); this effect was modified by trial day.
Conclusions and Clinical Relevance—Following inoculation with M bovis, calf behavior patterns were associated with both CIS and severity of pulmonary disease. Use of behavior monitoring systems may aid in recognition of respiratory tract disease in calves.
Changes in heart rate, heart rate variability, and atrioventricular block during withholding of food in Thoroughbreds
Authors: Ohmura Hajime , Boscan Pedro L. , Solano Adrian M. , Stanley Scott D. , Jones James H. 
Published: March 2012

Abstract
Objective—To determine whether withholding of food affects autonomic nervous system balance by analysis of heart rate (HR), HR variability (HRV), and frequency of second-degree atrioventricular block in horses.
Animals—5 healthy Thoroughbreds.
Procedures—For two 24-hour periods in a crossover study, food was withheld from horses or horses were maintained on their regular feeding schedule (control conditions) in their stalls and Holter monitor ECG recordings were obtained. The ECGs were analyzed by use of fast-Fourier transformation, and power spectrum densities were calculated for low-frequency (0.01 to 0.07 Hz) and high-frequency (0.07 to 0.6 Hz) variations in HR. Serum cortisol and plasma ACTH, norepinephrine, and glucose concentrations were measured at predetermined time points.
Results—Withholding of food resulted in significantly lower HR and more frequent second-degree atrioventricular block (the frequency of which was inversely related to the HR), compared with findings for control conditions. Circadian rhythms were similar during food-withholding and control conditions; peak HR was detected from 7:00 pm to 8:00 pm, and the lowest HR was detected in the early morning. During food-withholding conditions, the low-frequency and high-frequency components of HRV were significantly higher, and the low-frequency-to-high-frequency ratio was lower than during control conditions. Serum cortisol concentration was higher and plasma glucose concentration was lower at 6:00 pm in horses when food was withheld, compared with findings during control conditions.
Conclusions and Clinical Relevance—Indices of HRV seemed to be sensitive to changes in autonomic nervous activity and may be useful as clinical indices of the neuroendocrine response to stressors in horses.