bluuebunny/crossref_metadata_2025_split huggingface dataset:
Eliminating Bradenhead Pressure Using Novel Biomineralization Technology
Authors: Hiebert Dwight Randy , Griffin John 
Published: March 2023

Abstract
An oil well in Colorado had bradenhead pressure of 700 psi on the 9-5/8 in × 5-1/2 in annulus, prompting remediation to get bradenhead pressure below the 200-psi threshold set by the Colorado Oil and Gas Conservation Commission (COGCC) to resume production.
A biomineralization company was contracted by an operator in Colorado to apply their proprietary biomineralization technology to the well. Cement bond logs were used to identify a micro annulus around 3,050 ft. The well was prepared by setting a bridge plug at 3,062 ft, perforating at 3,056 ft and 3,052 ft, and running tubing to the depth of the bottom perforation. Biomineralizing fluids were then pumped into the well, where they formed crystalline calcium carbonate in the micro annuli.
After 36 hours of treatment, the injection rate dropped by several orders of magnitude. Subsequent monitoring by a state regulator determined bradenhead pressure had been eliminated and the well passed a mechanical integrity test without any additional intervention, allowing production to promptly resume.
Improved Bearing Design in Workover Motor Boosts Operational Efficiency for Plug Milling in North America
Authors: Unnikrishnan Vikram , Navin Guruswami , Breitenfeld Frank 
Published: March 2023

Abstract
Multi-stage stimulation in shale plays within North America land is still very predominant as of today and most operators continue with the already proven success of using frac plugs for zonal isolation. Post stimulation, intervention operation is carried out to remove the plugs via milling on coiled tubing or threaded tubing. Although dissolving or disintegrating plugs are gaining traction, vast majority is still of composite material and does require a proper bottomhole assembly (BHA) to ensure that the plugs are removed with maximum efficiency in one trip.
Coiled tubing (CT) service providers for milling frac plugs are using CT with an outer diameter (OD) ranging from 2" up to 2 7/8", with 2 5/8" becoming the new normal compared to the previous normal of either a 2" or 2 3/8". Primary driver behind the use of a larger pipe is to ensure that CT can get to the target depth (TD) with the required weigh on bit (WOB) as well as to maximize the pump rates for milling in long lateral wells (&gt;15,000 ft lateral length), thereby minimizing the need for short trips during the entire milling process. This increased flow rate and extended reach requirement in turn leads to the need for a more robust workover motor (WOM) that can handle the additional set down weights imparted on the BHA. Traditionally the WOM were derived from drilling services, where the process of hole making and stress acting on the motor is a lot different than the plug milling operations. Due to these differences, the reliability of the WOM can get compromised, which in turn will impact the operational efficiency.
This paper will discuss the steps incorporated to prevent drive sub failures, which were mostly caused due to the combination of bending load and torque transmitted by unwarranted stalling. The overload would cause a loss in compression around the upper radial bearing, which eventually leads to drive sub failing. Improvement potential was identified by increasing material strength and optimizing contact areas. Extensive modelling was carried out to improve the design, and materials with improved strengths were identified. Further, improvements were also incorporated into the lower thrust rings, both inner and outer. Field trials were conducted and based on the modifications, it was observed that the WOM failures were eliminated, thereby completing the mill outs in a single trip.
Improved design and material selection, helps in providing excellent service delivery, which in turn reduced the OpEx for customers carrying out plug milling in North America.
Completion Leak Repair with Corrosion Resistant CT Velocity String
Authors: Aguirre Erick , Nebiolo Martin 
Published: March 2023

Abstract
An operator company in Bolivia needed a solution to a corrosion and pressure integrity problem caused by the presence of CO2 gas in the production fluids, resulting in deep tubing corrosion over certain sections of completion components with measured penetrations up to 96% of tubing's wall thickness.
Based on the corrosion's profiles, the intervention objective was to install a 16% chrome corrosion-resistant velocity string inside the production string to produce the well avoiding the exposure of those highly corroded components from the tubing.
The repair intervention concept was to set a hydraulic packer over the lower completion below the most compromised section of the production string and connect the isolation packer with 2" OD 16%Cr coiled tubing pipe up to the surface, hanging the string on the wellhead.
The velocity string installation should be performed in a single run with the well in live condition, avoiding the need to kill the well during the intervention.
The well's lower completion was composed of TPC-fired guns, a combination of 2-7/8" 6.4# and 3-1/2" 9.2# N80 tubing, and a 7" 23-29# packer. The upper completion was basically an arrangement of 3-1/2" 9.2# N80 tubing with a retrievable SSSV set at 107 m, a sliding sleeve device, and a seal unit sub to connect the upper to the lower completion.
Subsea Well Annular Integrity Repair Using Coiled Tubing and Pressure Activated Sealant
Authors: Johns Joel E. , Anderson Chris , Anguiano Juan A. , Jones Steven 
Published: March 2023

Abstract
Production from a subsea well was halted due to hurricane activity in the Gulf of Mexico. When the well was returned to production, the annulus experienced a loss of pressure integrity. To achieve regulatory compliance and return the well to production, annular integrity had to be restored in a safe, expeditious manner. This paper will describe the process of operations undertaken to cure this well integrity issue utilizing pressure activated sealant deployed via coiled tubing.
Pressure activated sealants have been utilized for a number of years to efficiently cure leaks in a wide variety of applications. One of the first challenges to be addressed when considering a sealant repair is the method of getting the material to the leak site. For the purpose of the subsea well in question, coiled tubing was used to convey the sealant to the sea floor from a service vessel. An ROV then connected the coil to an external tree cap via a flying lead after which the sealant was introduced to the annulus by lube and bleed pressure cycles.
The annular integrity issue was analyzed in an effort to determine leak severity and location. Pressure trends noted at annular pressures of 4000 psi indicated a leak ranging from 0.15 – 1.5 lit/min. Gradient analysis indicated that the leak was deep in the completion potentially at a liner lap or the packer. Based on this information a sealant blend approximately 2 ppg heavier than the completion fluid was developed for the purpose of curing the leak. An external tree cap was installed on the well in order to provide access to the annulus of the well via a hot stab connection. About eleven cubic meters of sealant was transferred to the annulus through 2" coiled tubing extended to the sea floor connected to the well via a flying lead. A series of lubricate and bleed cycles were performed to accomplish this without exceeding predetermined pressure limits. After allowing the sealant to settle on the packer, annular pressure was maintained to allow the sealant to cure at the leak site. The pressure differential at the leak caused the liquid sealant to form an elastomeric seal. A positive pressure test was obtained shortly after the process and the well was returned to production.
An example of how using pressure activated sealants designed to polymerize only at a leak site affords options to expensive workovers on subsea wells will be provided herein. The use of this technology in concert with coiled tubing deployment represents an expeditious, economic approach to solving complex well integrity issues.
The Vital Role of Well Intervention Technologies and Techniques in Pushing the Boundaries in Extreme Well Completions
Authors: Duthie Laurie Simpson , Harthi Muhammad Awwadh , Saiood Hussain Ali , Afif Omar Tariq 
Published: March 2023

Abstract
The advantages of drilling extended reach wells (ERW’s) are well known; increased reservoir contact, reduced surface footprint and less wells drilled. Although the benefits of drilling these wells is clear, it is also essential to have the ability to conduct well intervention throughout the life of the well. Matrix acid stimulation and production logging are critically important well intervention operations for efficient reservoir management.
Coiled tubing (CT) is commonly deployed in ERW’s to perform these intervention operations. For open hole ERW’s, the success of the operation is often directly correlated to the length of the lateral covered. For ERW’s that can exceed 30,000 ft, the challenges to reach total depth (TD) can almost be insurmountable in terms of overcoming the high frictional forces acting against the CT. The level of difficulty is further magnified covering open sections often greater than 10,000 ft, where additional frictional forces are present from the rock, high dogleg severity and well trajectory. High bottom hole temperature along with high H2S & CO2 levels pose further challenges. Formation damage after drilling may result in serious production and therefore economic consequences and it is imperative to restore reservoir permeability along the complete interval with accurate treatment placement. The same challenges are present for logging operations where the main objective is to determine the flow profile along the entire open hole section.
To achieve the main objectives, a comprehensive approach is taken for these well intervention operations. Custom designed technologies have been developed to increase the open hole coverage achieved to provide good zonal coverage in matrix acid treatments and also a clearer understanding of multiphase flow from the formation during production logging. Technologies developed specifically to tackle these challenges are hydraulically powered CT tractors that can deliver up to 14,000 lbs pulling force and mechanical agitator tools that effectively reduce the total friction coefficient. Other technologies employed are a downhole compression/tension sub to monitor downhole performance in real time to enhance operational decision making. To extend the ultimate reach, certain techniques can add a few thousand feet in coverage. These techniques include high pressure jetting to clean out the horizontal section of the cased hole to lower the friction, strategically deploying friction reducer and using momentum assiduously.
These new technologies and applied techniques opens the window to ultimately meeting the goals of improved well surveillance and treatment in long horizontal laterals. Creative solutions have been core to inventing the best fit for purpose technologies, with great leaps having been made through pioneering technologies to extend CT reach in these extreme conditions.
Casing Leak Repair to Continue Hydraulic Fractures Stimulation
Authors: Ciminari Gaston Oscar , Cabo Gonzalo , Rimondi German , Duran Diego , Nebiolo Martin 
Published: March 2023

Abstract
A casing leak repair alternative is presented to allow continued hydraulic fracture treatment of an unconventional formation. Analysis of diagnostic operations, selection of the best alternative, and the results are detailed.
This paper details the diagnostic operations (annular circulation test, multifinger caliper log, leak chase with hydraulic packer on Coiled Tubing, fluid transit evaluation, and real-time camera downhole images acquisition) to identify the casing leak zone and the analyzed repair alternatives with the final selection of a casing patch.
To verify the pipe body shield strength and burst pressure post-patch expansion, a finite element analysis in dynamic condition was carried out to limit the hydraulic fracture pumping parameters.
This paper covers details on repair operations executed, verification analysis to confirm original frac treatment continuity, and lower & upper completion installation.
The diagnostics operations allowed pinpointing casing leak detection and selection of possible repair alternatives. The repair was carried out as planned involving many services companies.
A solution was implemented with local staff and services considering the COVID context with travel restrictions of the patch owners. Web broadcasting CT surface parameters allowed real-time support from casing patch suppliers during the entire intervention.
The completion plan with 24 frac stages performed through the casing patch was successfully executed.
The production packer with an OD of 99.5% of the casing patch drift was run through the casing patch and wireline set without any problem.
Considering well integrity conditions throughout the entire well production life as the main intervention objective, this paper introduces a successful alternative to repair casing failures on an unconventional well that allowed hydraulic fractures continuity to accomplish the original frac plan.
The well production was higher than the Estimated Ultimate Recovery (EUR) expected for the landing zone.
A Proven and Versatile Coiled Tubing Live-Well Intervention Solution from a Mono-Hull Vessel in the Norwegian Continental Shelf
Authors: Austbø Kjetil , Andersen Stein Kristian , Stuker John , Keong Azwan , Campos Jesus 
Published: March 2023

Abstract
The operator together with intervention-vessel company and several service providers together developed a versatile riser solution for coiled tubing (CT) operations from a monohull vessel already performing riser-less interventions. The solution covers 200 to 500 m water depths and converts back to riser-less after CT operations.
From concept selection, a one-team approach was emphasized to drive project performance and involvement among participants and to develop a collective culture. The vessel team collected 3D models of all equipment to check interfaces and to develop a training simulator; physical interface checks were also conducted to verify space on the vessel. Due to harsh weather in the Norwegian Continental Shelf (NCS), a series of analysis and yard tests indicated the need for wellhead load relief systems, an extensive live-well returns and solids removal system, a CT pipe tension process and a CT tension frame (CTTF) for both CT and wireline (WL) together.
The CT operations on 3 proof-of-concept wells were successful. The riser deployment and CT packages were rigged up and tested before the operation. During execution, CT was stabbed in the CT injector head after the riser was landed on the well; this eliminated the CT pipe clashing with the V-door during landing joint deployment and eliminated CT reel cycling due to heaves during standby. A rail system inside the CTTF converted from CT to wireline operations in under 3 hours with no crane nor winch.
Metocean data indicated 1% of significant wave height (Hs) would exceed operating limits. Some of those waves occurred during CT operation. The experience demonstrated limits for Hs could be expanded above 3.0 m. Trace amounts of oil were recirculated and the operation was simplified when oil-water filters were bypassed. Initially, it took 6 days to run work-over riser, and by the third well this was reduced to under 4 days due to the robust common culture during the operation and a parallel deployment of the riser disconnect package. The CT option was demobilized after the operation and the vessel returned to riser-less operations with zero recordable health, safety, and environmental (HSE) incidents.
In the NCS, these were the first CT live-well interventions from a monohull vessel. The 3 operations were performed with zero recordable HSE incidents. The novel vessel compensation system and CTTF demonstrated significant improvements in efficiency when swapping between wireline and CT. The innovative one-team approach was successfully emphasized and enabled fast learning and seamless integration of novel solutions from coiled tubing, wireline, well-test, subsea and other involved parties.
Reservoir Quality and Maturity Indicators Using Image-Based and Bulk Rock Characterization
Authors: Eichmann Shannon , Jacobi David , Srinivasan Poorna , Rodriguez Jennifer 
Published: March 2023

Abstract
Scanning Electron Microscopy (SEM) is used for source rock characterization to understand rock texture and compositional variations, porosity, and pore sizes. However, despite having significant benefits to characterization, obtaining quantitative results by SEM is time consuming and costly, and therefore the number of images collected per well is generally limited. Recent advances in image processing make obtaining quantitative data from images more accessible. This improves our ability to gather more image-based data on multiple wells for integration with larger scale measurements. Carbonate rich source rocks were sampled from several wells for SEM imaging. Large field-of-view SEM images were collected and segmented using supervised machine learning to label the pores, fractures/cracks, organics, high density minerals, and matrix minerals. Post-processing methods were used to correct mislabeled components. The relative amount of organic-contained porosity to total porosity (R1) and the relative amount of organic content to total porosity (R2) were calculated for each sample. Porosity was also obtained from crushed rock samples using the Gas Research Institute method. Pyrolysis was used to determine the productivity index and residual hydrocarbon content. Total porosity and organic content are two properties that are used to indicate rock quality. The results show that the R1 and R2 ratios from quantitative image-based analyses can be used to indicate potentially better quality. When compared across several wells of similar maturity, these quality metrics can be used to highlight wells with potentially better quality that warrant additional characterization. Finally, by comparing image-based data to that measured at larger scales, thermal maturity indicators can also be provided. This paper presents a method using image-based characterization to provide relative comparisons of reservoir quality between wells and a method to combine image-based and crushed rock analyses to compare source rock maturity. The results and workflow presented impact special core analysis for unconventional reservoirs and reservoir quality assessment and can complement characterization obtained by other methods.
Experimental Study on Microstructure of Temporary Plugging Zone and Relevant Plugging Capacity based on CT Images within Different Particulates Sizes
Authors: Zhao Feng , Guo Chun Jian , Ren Chuan Ji 
Published: March 2023

AbstractTemporary plugging fracturing technology is an effective way to control fracture propagation in shale oil and gas development. However, insufficient plugging pressure often causes the failure to promote new fractures. Therefore, it is essential to reduce plugging permeability and increase plugging pressure. The permeability of the plugging zone is closely related to its pore structure, so the quantitative study of microscopic pore structure can provide a basis for reducing permeability. This paper introduces a new method based on micro-CT to characterize the microstructure of temporary plugging zones. Three kinds of particulate temporary plugging agents with sizes of 2-4mm, 1-2mm, and 0.4-0.8mm were used as the research objects. The samples of the temporary plugging zone in natural accumulation and compaction state were prepared by a self-made mold. The total pore structure and parameters (porosity, pore radius, pore throat, and tortuosity) were obtained by three-dimensional (3D) reconstruction of CT images. Finally, the displacement device was used to test the plugging pressure of the temporary plugging zone. Under natural accumulation, the porosity and tortuosity of the temporary plugging zone are independent of particulate size. The pore radius decreases with the decrease of particulate size. In the compaction state, particulates and particulates are cemented with each other, resulting in apparent changes in the pore structure. With the decrease in particulate size, the pore structure changes more obviously. For example, the pore radius of 2-4mm decreases from 889.27um to 736.33um, while the pore radius of 0.4-0.8mm decreases from 370.15um to 63.94um, with a reduction of 82.9%. The plugging pressure test results are consistent with the microscopic pore results. In conclusion, the smaller the particulate, the easier the particulate compression deformation, the smaller the pore radius and porosity, and the denser the plugging zone. Although small particulate-size temporary plugging agents can produce large pressure, forming an effective plugging zone in the fracture is difficult. Therefore, large particulates can bridge the fracture, and small particulates are filled in the pores of the plugging zone formed by large particulates to generate a tight plugging zone. In this paper, we provide a new application of Micro-CT for quantifying the microstructure of the temporary plugging zone. The effect of the properties of the temporary plugging agent on the structure of the plugging zone can be clarified from the microscopic point of view by using this method, which provides a new means for the design and optimization of temporary plugging materials.
EFTVG: An Energy Efficient Fuzzy–Timer Clustering Approach in an Adaptive Virtual Grid Cluster Based WSN
Authors: Mazinani Armin , Mazinani Sayyed Majid , Alyasiri Mohammed Jasim Mohammed 
Published: March 2023

Abstract

Clustering is an effective way that improves WSN lifetime. In this paper, unlike the other approaches, an adaptive virtual grid is conducted to form cluster boundaries during network lifetime. Using the adaptive virtual grid not only shrinks the size of clusters but also determines network configuration based on the location of the base station. In EFTVG, compared to the previous clustering methods which used a specific cluster head selection procedure for the entire network lifetime, we propose a consecutive clustering (fuzzy-timer) approach. Authors divide the network lifetime into two parts. Firstly, a fuzzy clustering is applied to address uncertainty in a semi-distributed manner. Then a timer-based clustering is used in the second part to tackle sharp energy consumption in a fully-distributed manner. A local threshold is applied in each cluster to specify whether cluster head selection is required or not. Using this novelty, the network may encounter new cluster heads in some clusters, while we trust the ex-cluster head in others. Applying this policy results in energy saving. Finally, we present a novel hybrid routing to reduce energy consumption in WSN. EFTVG is compared with MOFCA, EAFCA, EAUCF, FLECH, DECUC, FUCA, DUCF, FSVGA and FMCR-CT approaches in four different scenarios.