bluuebunny/crossref_metadata_2025_split huggingface dataset:
Evolution of a Pinpoint Stimulation Technology and the Benefits Thereafter
Authors: Hartley J. , Holden D. 
Published: March 2013

Abstract
The buildup of the energy services industry in recent years has led to an unprecedented amount of hydraulic horsepower (HHP) available to energy producing organizations. This, combined with the decline of natural gas prices in North America during recent months, has made the energy services market (specifically, pressure pumping) more competitive than ever. Energy services companies must not only provide HHP, but also innovative, efficient solutions and technologies to satisfy the energy producers’ hydraulic fracturing needs. Pinpoint stimulation that uses hydrajet perforating is one such technology that provides both innovation and efficiency.
Historically, setting proppant plugs for interval isolation in horizontal/deviated wells by means of traditional techniques has proven to be challenging for various reasons. As energy producers began drilling more of these types of wells, they created a need for a reliable proppant plug setting technique for multi-interval Pinpoint stimulation operations. The traditional method of setting a proppant plug is by simply reducing the downhole pump rate and increasing the proppant concentration, thereby inducing a near wellbore (NWB) screenout. By starting with a proven Pinpoint stimulation solution and adding a new coiled tubing (CT) deployed bottomhole assembly (BHA), Pinpoint stimulation process efficiencies were increased in many ways, proppant plug setting being just one.
The new BHA enables the proppant plug to be set while hydrajet perforating the next interval, minimizing the time and materials required. It also assists in anchoring and centralizing the hydrajetting tool during perforating operations to help ensure that the jets remain on target with the proper standoff distance. These new developments, as well as those included in the operational procedures for using this new BHA, elevate fracturing treatment efficiencies to a new level.
This paper presents the development of the new BHA from its inception to its current form, including information on its operation. It also details how the new BHA can provide North American energy producers with the process efficiencies they are seeking, and how this BHA can assist energy producers in other areas of the world that are underserved in the area of HHP reach their goals.
First Field Application of 2-7/8" Scale Removal Tool for Offshore Well Abandonment
Authors: Birk Navneet 
Published: March 2013

Abstract
In June 2010, as part of an operation in a producing well, offshore eastern Canada, a junk basket on wireline tagged its depth and became stuck. The bottomhole assembly (BHA) was disconnected and left in the well. When the wireline was back at surface, scale was determined to be the reason for getting stuck. This became more evident after an attempt was made to bait the fish, which was unsuccessful because loose scale had settled on top of the disconnected tool. A run was made with a lead impression block (LIB) to understand better the fish neck, but it returned with no impression. Previously, in 2005, naturally occurring radioactive material (NORM) was detected in this well, having been observed on logging tools returned back to surface. Similarly, a few years later, NORM scale concerns appeared in another producing well on the platform. Due to the inability to handle large amounts of NORM (mostly loose scale) on surface, no intervention work to date had been performed on this platform.
The proposed solution was to perform a scale removal operation using coiled tubing (CT). Initially, a pilot hole was drilled with a motor and mill, but the main focus was the use of a 2 7/8-in. scale-removal tool that employed jetted beads. For optimal pump rates and suspension capabilities, a specific gelled fluid system was recommended. A shaker system was sourced to remove and contain solid cuttings on surface and to recycle the gelled fluid on surface by using two large fluid containment tanks.
The operation was completed successfully and without any issues or concerns. Client was able to recover the slot for future sidetrack drilling, which is a priority on a fixed platform.
First Real-Time DTS Inversion Job Worldwide
Authors: Lopez Victor H. , Castillo Marco A. , Custodio Rafael , Worden Sarah , Romandia Miguel Gerardo , Ramondenc Pierre , Rueda Felipe L. 
Published: March 2013

Abstract
The production curve of the main Mexican offshore fields has been decreasing rapidly year-on-year, representing a challenge to the eighth-largest oil producer country and an opportunity to implement new techniques for workover (WO) operations to increase production recovery.
Within the most common WO activities developed in offshore Mexico is acid stimulation of carbonates, which was developed as pumping a large volume of fluids (solvents, HCl 15%, etc.) with minimum control for zonal coverage. Conventional coiled tubing (CT) jobs have improved this technique with the use of impact jetting tools to remove damage at the tubular and perforation holes and placing the treatment in the desired area. The estimation of fluid injection per zone has been evaluated using radioactive traces. However, the estimates of where the fluids go lack accuracy, and the radioactivity poses additional risks related to hazardous material handling.
In 2009, a new interpretation technique to evaluate the treatment zonal coverage appeared that used CT with fiber optics. This distributed temperature sensing (DTS) enables the equipment to record temperature readings at several predetermined depths over time creating a survey that identifies, qualitatively, the admittance of the treated pay zones based on the formation’s cold-down/heat-up effects. Unfortunately, this technique had some limitations as the data recorded needed to be converted, interpreted, and then translated into common oilfield language in the form of graphics and data tables. The time to get a final result from the readings to the customer was so long that the window to modify the current treatment to improve the well response was, on most occasions, already closed.
DTS inversion brings a "real-time DTS matrix stimulation evaluation product" by using an inversion algorithm coupled with a fluid placement model to accurately quantify the amount of treatment placed across the treated zones of the well. A detailed case history from an offshore Mexico well describes the first worldwide real-time DTS inversion job and illustrates the workflow and advantages of this technique. The results from the technique showed a direct match with a previous evaluation of the formation through production logging conveyed on Wireline tools.
The First Implementation of Well Interventions by a Full Catenary Coiled-Tubing System With a Dynamic Positioning Vessel with Compensated Gangway
Authors: Wattanasuwankorn R. , Ashby S. , Hammer F. , Long N. , Song Y. , Ahmed J. A. 
Published: March 2013

Abstract
An offshore operator in Brunei faced the challenge of increasing the injectivity in water-flooded fields to improve hydrocarbon production. The solution chosen was to use a stimulation vessel with coiled tubing (CT), nitrogen, and pumping capability to perform well interventions to achieve the injection targets. The operation faced challenging offshore weather conditions, limited platform access, lack of crane facilities, aging offshore facilities, and had to provide an emergency disconnect system, while improving the operational efficiency from existing methods.
The stimulation vessel was used in conjunction with some new concepts to the CT offshore operation. These novel concepts included using a full catenary system for CT operations, a dynamic positioning vessel, a knuckle boom crane, and a heave compensated gangway. The full catenary system was selected for the CT operation to minimize lifting hazards, improve equipment installation lead times, and improve the stimulation vessel operating efficiency. The dynamic positioning vessel eliminated anchoring requirements and provided enhanced efficiency for evacuation and approach to offshore facilities. The knuckle boom crane provided the capability to lift in different angles for equipment placement in difficult positions, even underneath a platform helideck. The heave compensated gangway provided extremely safe transfer of personnel between the stimulation vessel and the offshore facilities. It also provided a safe emergency response and evacuation facility in the event of sudden severe weather, platform emergency, or worsening sea conditions.
The advantages and benefits of using these concepts for offshore operation have resulted in a significant improvement in terms of operational efficiency and safety for the stimulation vessel.
Real-Time Abrasive Perforation on Coiled Tubing Saves Operation Time, Improves Cost Efficiency and Boots Reservoir Production in Delta Mahakam Field's Low-Porosity Reservoirs
Authors: Purwitaningtyas I. M. , Mezie-Okoye S. O. , Sugiarto T. , Wardhana R. A. 
Published: March 2013

Abstract
The Delta Mahakam’s geology is characterized by multiple layers of thin, heterogeneous reservoirs separated by a few meters. These wells are traditionally perforated with the conventional wireline method. However, at reservoir porosities less than 11%, perforations yielded less than 60% of flowing probability. With the increase in drilling activity and the number of reservoirs with low porosities, we began to evaluate the effectiveness of perforating these reservoirs with abrasive jets perforation conveyed on coiled tubing (CT).
To improve depth accuracy and monitor real-time bottomhole conditions, the abrasive jet perforating tool was run on fiber-optic CT. Pressure measurements inside and outside the coiled tubing enabled the pumping rate of the abrasive fluid to be adjusted as necessary, improving perforating efficiency as well as the GR/CCL reading for the depth correlation.
This abrasive perforation method was applied in six different wells in Delta Mahakam field; the design, execution, and evaluation of this method is presented. From the first well to the last, this alternative perforating strategy helped increase reservoir production, improve cost efficiency, and by adding the real time monitoring system on coiled tubing it is proved of reducing the operational time by up to 45%. This method proved to be a viable alternative to wireline-conveyed perforating in the Delta Mahakam field.
Job Planning and Execution when Fishing Live Perforating Guns with 8,000-psi Surface Pressure
Authors: Sredensek E. , Sanders H. 
Published: March 2013

Abstract
An operator had live perforating guns stuck in the casing at 14,100 ft. The wireline had been pulled out of the rope socket, leaving 67 ft of wireline tools, perforating guns, and plug assembly stuck in the wellbore with 8,300-psi surface pressure. To remediate this issue, a 144-ft tall snubbing unit rigup was employed using eleven 7 1/16-in. 15K-psi blowout preventer (BOP) cavities and 78 ft of riser spool. Job preparation included standard prejob planning analysis to help resolve work string buckling risks and to establish the work string’s maximum safe load limits based on the well conditions and operational requirements.
This challenging high-pressure fishing job was executed as planned and without incident. The snubbing unit was rigged up, pressure tested, and operational within five days of equipment arriving on location. The snubbing unit crew successfully latched and recovered 97 ft of fish and work string bottomhole assembly (BHA) to surface under high pressure without incident.
This paper explores the level of prejob due diligence analysis required for the basic planning of high-pressure snubbing work. Surface buckling analysis, work string condition, and pipe tension/collapse considerations are applied and discussed in this case history.
Real-Time Evaluation of a Velocity String: Case History of a Suitable Solution for Well Recovery
Authors: Castaño D. A. , Ruiz N. , Zabala R. , Mora E. , Nava D. J. 
Published: March 2013

Abstract
Cupiagua field, Colombia, is a condensate gas field with typical completions of large tubing sizes, 7in. and 5 ½ in., and some wells experience a serious problem for lifting fluids due to the high water cut and low gas rate. This document presents the case history of a well with complex reservoir damage and a challenging well integrity situation that narrowed the options for well interventions. An operation with coiled tubing(CT) in conjunction with real time telemetry through fiber optics was performed to evaluate the remaining potential of the formation and assess the velocity string option using a 1 ¾ in. CT to reduce the wellbore transverse flow area, thus improving the vertical lift performance. Also, nitrogen was injected at gas rates between 1and 2 MMscf/D to simulate the combination of the velocity string and a gas injection system. The surface and downhole data collected allowed the engineering team to select the best ofseveral options for the recovery of the well.
Zone Abandonment with E-Line Inflatable Bridge Plug Provides Work-Around for Platform with Coiled-Tubing Access Limitations
Authors: Osorio Alejandro , Frisby Ray 
Published: March 2013

Abstract
An operator working in the North Atlantic off the coast of Newfoundland, Canada required a downhole barrier to permanently abandon a set of depleted perforations. Platform limitations restricted the use of traditional methods to abandon the zone located in a nearly horizontal lateral well. The operator elected to set a high expansion inflatable bridge plug on wireline in a highly deviated section and spot cement on top of it to abandon the zone.
There were several challenges involved in this application including the requirement for the bridge plug to expand by more than 200% of its run-in diameter due to wellbore restrictions and deviation. E-line was required to provide power for the wireline tractor because a coiled tubing unit could not access the well slot due to the positioning of the rig on the platform. Additionally, the bridge plug had to withstand a 3,000 psi differential pressure test and hold for several weeks without the aid of cement until coiled tubing could be deployed to place cement on top.
The plug was successfully set and held the required pressure. Three weeks after, the platform derrick was moved to another slot and coiled tubing access was again available. The plug was again tested to 3,000 psi and cement was placed on top of it to establish a permanent barrier. A high expansion inflatable bridge plug setting system run in conjunction with a wireline tractor provided an optimal solution for this application.
Using this inflatable bridge plug setting system in conjunction with a wireline tractor represented substantial savings in rig time and operational costs. The operator was able to perform all necessary integrity tests to confirm hydraulic isolation and successfully abandon the zone. The bridge plug deployment system is capable of pumping downhole wellbore fluids to set the plug without a coiled tubing unit or pumps on location. E-line was used to support the tractor through high deviation however; the bridge plug deployment system can alternatively be deployed on slick-line or with a coiled tubing tractor.
Optimal Sand Cleaning Algorithms for Planning and Executing Electric Wireline Suction Tool Operations
Authors: Nunez W. , Perez L. , Schwanitz B. 
Published: March 2013

Abstract
Conventional methods used for downhole sand or debris cleaning have considerable investments in economic costs and time. Scheduling these activities to minimize production interuptions and to maximize unrestricted flow is a constant challenge faced by production and flow assurance engineers in the Oil & Gas industry. A sand and fill cleaning decision can be expressed as an optimization problem since its purpose is to maximize the production of the well to accomplish production goals at the end of a time period.
This paper presents optimization algorithms applied in dynamic programming to help in scheduling cleaning interventions for wells in order to maximize the continuous production under physical, technical and economic considerations while minimizing the investment cost of the total operation. A strategy will be presented which takes into account mainly the fixed costs but also the variable costs and sensitivity analysis that allow the model to better approximate reality. The strategy considers three options based on the costs of cleaning with either electric line or coiled tubing technology; 1) to completely remove a given volume of sand, 2) to clean to a minimum acceptable level or, 3) not to clean and allow sand volume increases to continue.
The cost to perform sand cleaning with a certain technology based on a mathematical function, considers the following requirements:the relationship between volume of sand produced per unit time, Vt (flow),(Vmax-Vmin) or the interval between Vmax in which production of oil is minimized and the Vmin for maximum production,the time horizon to perfom the sand cleanings, andPoints that make the operation unfeasible such as physical restrictions in the well or operator time/cost constraints.
This paper will also present two cases demonstrating the strategy to schedule cleaning interventions that achieves a set production goal.
Break the Friction: Chew the Plug for Faster Completions on Coiled Tubing
Authors: Gilbert Landry G. , Skyles Lane P. , Smith Lee M. , Davis Gary W. , Medlin Kevin G. 
Published: March 2013

Abstract
Once the decision is made to complete a well in order to begin producing, the operator wants to complete the task as soon as possible. One completion task is to drill through multiple completion plugs so the pay zones can begin producing. In the past, drilling these plugs has gone slower than desirable due to static friction build-up between the coiled tubing string and the hole wall. In addition, slower plug drilling results as the drill bit dulls after drilling several plugs.
This paper introduces a friction breaking tool/drill bit combination that has shown to lessen plug drilling time by almost double what was previously possible. The friction physics between hole wall and coiled tubing will be presented in the initial portion of this paper. Then, the simple designs of the friction breaking tool and the drill bit will complete the design portion of the paper. Finally, a Case Study is provided to show the results of running these tools. The Case Study took place in Tarrant County, Texas while drilling out composite completion plugs to complete four wells.
Accelerating the Learning Curve: Adapting Global Expertise to Coiled-Tubing Operations in Argentina Shale Development
Authors: Sergio J. , García R. , Moll Juan M. , Olivas José , Nebiolo Martin Mauro 
Published: March 2013

Abstract
World energy demand has led unconventional reservoirs to become a focal point for operators worldwide. In some regions, including North America, unconventional resources have been developed successfully, accumulating important experience and lessons learned in the process, allowing these resources to become important contributors to countries’ energy production. In an attempt to reproduce this effect in other regions, operators are also looking into important unconventional reservoirs outside North America. Currently the world’s third-largest shale oil and gas resources holder, Argentina has become a key focus for many operators initiating exploration and development operations. This brings many challenges to operators trying to take over this market as quickly, efficiently, and safely as possible.
When developing unconventional reservoirs in the magnitude expected, one of the most important challenges for service companies and operators in Argentina is effectively grasping the global expertise, best practices, and lessons learned from these types of operations and adapt them to the local environment. This should reduce the learning curve experienced while starting a new development. A key component of these challenges includes all coiled tubing (CT) interventions involved in well completion; expertise in CT intervention is critical because of the risks concerning these operations, which include wellbore calibration, perforating, fracture plug drillouts (FPDOs), and sand cleanouts. Overcoming this challenge can translate into valuable time and cost reductions and allow operators to reach the efficiency that took years to attain in other parts of the world in much less time.
Lessons learned and best practices incorporated from global experience, in addition to the local ideas, contributed to the implementation of CT interventions for the shale startup and beginning of the development phase in Argentina. Statistics and results from jobs performed in these reservoirs in its first year since startup reflect the changes and adaptations undertaken to successfully develop the shale resources in Argentina and to inform future plans for this rapidly evolving market.
A Metallurgical Look at Coiled Tubing
Authors: Coloschi M. , Gomez G. , Mitre J. , Nguyen T. , Reichert B. , Valdez M. 
Published: March 2013

Abstract
Coiled tubing has been traditionally characterized by its mechanical properties in order to guarantee that the structural response of the tubing is uniform and satisfies current standards along its full length. Also the tubing is generally fatigued tested in order to characterize its responses under simulated field conditions. As coiled tubing applications become more challenging, there is a need for higher mechanical properties, better resistance to severe environments and a better relative fatigue performance in the tube body and bias weld. The limitations to develop a product that satisfies these new requirements can not be understood solely based on coiled tubing mechanical properties, but extensive metallurgical analysis must be performed.
In this study, the relevance of the metallurgy basis in each of the production steps was reviewed in order to understand the limitations of current manufacturing process. This understanding, coupled with the goal of developing new products that satisfy new market demands, has resulted in a complete redesign of the manufacturing process. Preliminary results of a new manufacturing process have proven to provide a path for current and future innovative products.