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zonal isolation
This course examines methods for detecting fluid channels, voids and leaks, and how to repair them. It also covers the logging tools and technologies use to evaluate the integrity of the cement prior to initial completion or anytime during the life of the well. The first day of class is dedicated to evaluating cement and the second day to repairs. Poor cement coverage affects nearly every aspect of a well. This course will give you a better understanding of some critical well safety and integrity issues.
Effective Cementing Solutions for CCS Wells is a half-day Training Course that will focus on the challenges of completing and cementing Carbon Capture and Storage wells. For CCS wells, the design should start with the completion size required to achieve the desired CO2 injection rate. Dual containment is essential; the second barrier must not only be designed for the corrosive environment but the second barrier and its associated equipment must be periodically inspected or tested. The differences between CCS wells and conventional oil and gas wells require a different approach to well design. If CCS wells were to be designed using established methods for oil and gas, the wells might fail to maintain integrity to prevent undetected migration of stored CO2.
Abstract One of the challenges encountered in hydraulic fracturing of unconventional resources is casing deformation. Casing deformation statistics vary across different regions of the world, but it is estimated to affect 20-30% of horizontal wells in some areas of operations. The consequences of casing failures can be varied but, in many cases, it affects the well production, wellbore accessibility and in some rare instances presents a situation of well control and its associated risks. Incidentally, most literature on casing deformation pertains to "plug & perf" fracturing operations in cemented completions though pipe deformation is known to occur in multi-stage fracturing (MSF) sleeves type of openhole completions as well. Intuitively, the two failure mechanisms may appear similar instead they represent very diverse well conditions that lead to pipe deformation. Tubular damage during fracturing is not caused by a single, consistent reason. Multiple mechanisms may be responsible for casing deformation; formation rock properties, wellbore configuration, cyclic loads acting on the tubulars, tubular quality, cement bond, or simply some operational aspects during drilling and completion conducive to pipe deformation. Tubing stresses analysis of the lower completion and especially of the individual components of the openhole MSF completion is seldom done. A comprehensive study was initiated by first validating the key data and parameters, multi-arm caliper data in conjunction with downhole camera imaging, and review of the physical mill-out patterns of frac plugs (in cased hole completions) and ball-seats used in MSFs to understand the damage pattern. This work was supported by detailed geo-mechanical properties profiles, diagnostic injection tests analysis, and evaluation of casing integrity under anticipated fracture loads. One of the primary learnings from this study was that wellbore quality had a significant bearing on the post-frac wellbore integrity for both types of well completions. The study indicated that well profile, design, and tool placement in the well also had a strong influence on axial load distribution in open-hole multistage completions. The mode of failure in openhole multistage wells was different than those seen in cemented liners. These differences do not necessarily fall under the domain of formation movement experienced in geomechanically complex and tectonically active areas. Since reservoir uncertainties are a reality, a good wellbore quality cannot always be guaranteed. It becomes necessary to manage pipe deformation with mitigating practices. This paper provides practical solutions to pipe deformation in cemented and openhole completions. The operational workflows allow upfront assessment with analytical tools to model the stress loads. By understanding the primary factors that affect well integrity, the likelihood of casing failure can be predicted and avoided ahead of time, save fracturing costs across high-risk areas, and not jeopardize production from multimillion-dollar completions. Managing well integrity is essential for development of hydrocarbon resources while preserving the environment and assuring safety of personnel.
- Asia > Middle East (0.68)
- North America > United States > Texas > Harris County > Houston (0.28)
- South America > Argentina > Patagonia > Neuquén > Neuquen Basin > Vaca Muerta Shale Formation (0.99)
- South America > Argentina > Patagonia > Neuquén > Neuquen Basin > Loma Campana Field > Vaca Muerta Shale Formation (0.99)
- South America > Argentina > Patagonia > Neuquén > Neuquen Basin > Loma Campana Field > Lower Agrio Formation (0.99)
- (2 more...)
- Well Drilling > Wellbore Design > Wellbore integrity (1.00)
- Well Drilling > Drilling Operations > Directional drilling (1.00)
- Well Completion > Well Integrity > Zonal isolation (1.00)
- (4 more...)
Abstract Many of the new completion technologies were introduced to address the challenges related to the increasing well complexity and the advancement in the downhole high-pressure high-temperature (HPHT) realm. This paper focuses on the evolution of Nonmetallic sealing technologies used in downhole completion tools, from the simple O-ring based chevron stacks to the energized hybrid composite seals. Furthermore, future advances in seal development are discussed to tackle the new corrosive challenging environments. A literature review and subject matter expert input were gathered to study the nonmetallic seal design technologies and tool applications. The topics covered include material selection; chemical and environmental resistance; mechanical design and characteristics; durability and abrasion resistance; rigors of verification and life validation testing; challenging corrosive downhole scenarios for seals; and harnessing the environment to create application-specific seals. Various categories of sealing functions are discussed, including tubing/annulus barriers, static/dynamic sealing configurations, and temporary/permanent applications. Sealing technology selection for every downhole tool in the completion string is crucial to ensure safety, reliability, and profitability of a well completion for its planned life. This paper provides a reference with guidelines and best practices for reservoir and production engineers. Often, collaboration projects between operators and service providers can help in developing tailored and advanced Nonmetallic solutions. An understanding of sealing technology will assist in efficient project execution and curated design assurance.
- Asia > Middle East (0.93)
- North America > United States > Texas (0.29)
- Energy > Oil & Gas > Upstream (1.00)
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (0.98)
Engineered Ultra-Low Invasion Loss Control Solution Allows Circulation, Ensuring Cement Placement and Zonal Isolation in Liner Cementing Jobs and Through Coiled Tubing – Case Studies
Fazal, Muhammad Adnan (Sprint Oil and Gas Services FZC) | Ahmad, Syed Hamza (Sprint Oil and Gas Services FZC) | Yousuf, Arif (Sprint Oil and Gas Services FZC) | Rehman, Aziz ur (Sprint Oil and Gas Services FZC) | Noor, Sameer Mustafa (Oil & Gas Development Company Limited) | Nazir, Irfan (Oil & Gas Development Company Limited)
Abstract The conventional loss cure techniques are largely reactive and include addition of coarse grade particle, fibrous material and other viscous pills that are lost into formation during loss cure attempts. Being highly invasive, these loss cure solutions block pore throats and line producing fractures causing considerable formation damage and loss of net asset value. Moreover, these techniques pose additional challenges while placing thru slim liners and coiled tubing (in rigless applications) due to elevated risk of getting the circulation ports plugged. Moreover, during the era of technological revolution and decarbonization, an effective and efficient solution aids to promote the practices producing low carbon emission. The proactive wellbore shielding loss cure is a particle size distribution-based LCM solution having excellent fluid loss properties and exhibiting low permeability barrier at the fluid-rock interface. The low permeable shielding effect offers less invasion across a broad range of pores (1microns to 4,000microns) and thereby protecting formation from any permanent impairment. The solution covers the wide range applications of loss cure throughout well life ensuring zonal isolation and saving significant rig time. Customized particle size distribution does allow LCM solution to be pumpable thru liner complying the allowable particle sizes (less than 1,000microns) and concentrations (upto 18 lbs/bbl) and for coiled tubing specialized applications with allowable particles size of 100 microns while maintaining rheological properties (Fluid Loss<50 ml/30 min, 5lbs/100ft2>Ty<10lbs/100ft2 & PV<90 cp). This paper demonstrates the working principle and practical applications of engineered solution for loss cure and successfully achieving zonal isolation in 7" liner being placed as pre-cement spacer in naturally fractured formation. The wellbore shielding pre-cement spacer ensured the cement rise above loss point thus achieving zonal isolation in partial to complete losses environment and helps in minimizing formation's impairment. The same approach was adopted to cure losses in rigless with coiled tubing in both carbonate and sandstone reservoirs for well killing and zonal isolation without plugging the CT BHA and circulation ports while complying design requirements.
- South America (0.68)
- Asia > Middle East (0.28)
- Well Drilling > Wellbore Design > Wellbore integrity (1.00)
- Well Drilling > Pressure Management > Well control (1.00)
- Well Drilling > Drilling Operations (1.00)
- (8 more...)
Abstract The Dilemma of Limestone Formations is their temperamental nature. The same conductivity that threatens with Loss also promises production and at the same time deceives log outputs. Presence of conductive fractures is characteristic of these carbonates and even if the operator does drill past these thief zones via controlled drilling ECDs and LCM loaded systems, the hazard is never eliminated. One of the poorest timing for this menacing loss to resurface is during cementing of these reservoir carbonate sections, when ECDs tend to rise as soon as the cement slurry dares rise above the loss zone. Conventional LCMs are not the candidate for formation strengthening and cementing every loss zone can be rather tiresome for the drilling time-depth curves, not to forget damaging to the reservoirs. So, the approach to case these conductive carbonates while maintaining their conductivity remains a work in progress for the cementing technical community. This paper suggests not to merely drill through or fight against the loss but to mould the formation properties to operator's requirements. The stress caging technique may be one of the key puzzle elements to strengthen fractured limestones and their successful cementing.
- North America > United States (0.47)
- Asia > Pakistan (0.33)
- Europe > Norway > Norwegian Sea (0.24)
- Geology > Rock Type > Sedimentary Rock > Carbonate Rock > Limestone (0.50)
- Geology > Geological Subdiscipline (0.48)
Summary Sealing elements (SEs) of fracture plugs have crucial roles to isolate target zones of a well in hydraulic fracturing. If the zonal isolation by the SE is not adequate, it can result in erosion of the casing. To the best of the authors’ knowledge, the effect of casing deformation on sealing performance is not well researched or understood. To study the effect of casing deformation on sealing performance, finite element analysis (FEA) of SEs in oval casings was conducted in this study. Finite element simulation of a degradable fracture plug with three different casings ovalities (0%, 2%, and 5%) and three different SE designs (O-ring type, short type, and traditional long type) was conducted to evaluate deformation behavior and sealing performance of SEs in deformed casings. Contact pressure (CPRESS) on the casing by the SE after the plug was set in the casing and the risk of leakage were discussed and compared for each design. In the casing with 0% ovality, all the SE designs established contact with the inner surface of the casing when setting force was applied. However, for the O-ring-type design, the area in contact with the casing was small and it may result in leak and erosion in the actual well if there is a small dent or deformation on the casing. When there is ovality in the casing, the minor inside diameter (ID) has a smaller ID and the major ID has a larger ID compared to the nominal ID of the casing. In the casing with 2% and 5% ovality, neither O-ring-type SE (O-SE) nor short-type SE (S-SE) could contact the major ID of the casing and there was a gap between the inner surface of the casing and the SE. This gap can cause erosion of the fracture plug and casing when the fluid passes through the gap. In contrast, the traditional long-type SE (L-SE) contacted both major and minor IDs of the casing, and no gap was observed. This result indicates that there is a potential risk of insufficient isolation of target zones and erosion of casings in actual well conditions if fracture plugs with S-SEs are used. Because there are various types of fracture plugs with different SE designs, this study helps to select proper fracture plugs with good SE design and mitigate the risk of erosion of casings and plugs. As this study is based on FEA simulations, future demonstrations through experiments and field trials are needed.
- Asia (1.00)
- North America > United States > Texas (0.70)
- North America > United States > South Dakota > Williston Basin (0.99)
- North America > United States > North Dakota > Williston Basin (0.99)
- North America > United States > Montana > Williston Basin (0.99)
- Asia > China > Sichuan > Sichuan Basin > Weiyuan Field (0.99)
Zonal Isolation Material for Low-Temperature Shallow-Depth Application: Evaluation of Early Properties Development
Agista, Madhan Nur (University of Stavanger (Corresponding author)) | Khalifeh, Mahmoud (University of Stavanger) | Saasen, Arild (University of Stavanger) | Yogarajah, Elakneswaran (Hokkaido University)
Summary Shallow-depth cementing presents unique challenges due to its low temperature and low pore pressure characteristic. The curing process of the cementitious material is typically prolonged at low temperatures resulting in a delayed curing process. The use of a low-density slurry to mitigate low pore pressure introduces another challenge, as it leads to a reduction in the final compressive strength. On the other hand, the operation requires the material to develop enough strength swiftly to be able to efficiently continue the next drilling operation. In addition, the presence of flow zones such as shallow gas and shallow water flow increases the complexity of the cementing process. There have been many developments in cementitious materials for shallow-depth cementing such as rapid-hardening cement and gas tight cement. However, there is little research focusing on the performance evaluation of each material at low-temperature conditions. This paper aims to present a thorough material evaluation for low-temperature shallow-depth cementing. The incorporated materials are American Petroleum Institute (API) Class G cement, rapid-hardening cement, gas tight cement, and geopolymer. Geopolymer is included to evaluate its potential as the green alternative to Portland-based cement. The sets of characterization were conducted during the liquid, gel, and solid phases. The samples were prepared under wide-ranging low temperatures and typical bottomhole pressures for shallow sections. The result shows different performances of each material and its behavior under low temperatures such as prolonged strength development and low reactivity, which necessitates further development of these materials.
- Asia (0.93)
- Europe > United Kingdom (0.46)
- North America > United States > Texas (0.28)
- Geology > Geological Subdiscipline > Geomechanics (0.69)
- Geology > Mineral > Silicate (0.69)
Effect of Calcium Expansive Additives on the Performance of Granite-Based Geopolymers for Zonal Isolation in Oil and Gas Wells
Gomado, Foster Dodzi (Department of Energy and Petroleum Engineering, Faculty of Science and Technology, University of Stavanger (Corresponding author)) | Khalifeh, Mahmoud (Department of Energy and Petroleum Engineering, Faculty of Science and Technology, University of Stavanger) | Saasen, Arild (Department of Energy and Petroleum Engineering, Faculty of Science and Technology, University of Stavanger) | Sanfelix, Susana G. (Department of Engineering, Faculty of Computer Science, Engineering and Economics, Østfold University College) | Kjøniksen, Anna-Lena (Department of Engineering, Faculty of Computer Science, Engineering and Economics, Østfold University College) | Aasen, Jan Aage (Department of Energy and Petroleum Engineering, Faculty of Science and Technology, University of Stavanger)
Summary Geopolymers have emerged as a promising alternative to Portland cement for oil and gas wells. Achieving effective zonal isolation by use of geopolymers may require controlling their expansion. This study investigates the effect of calcium oxide (CaO) as an expansive agent on the performance of geopolymer-based sealing materials. Specifically, we explore the impact of CaO reactivity on various material properties using isothermal calorimetry, Brunauer-Emmett-Teller (BET) surface area analysis, linear expansion (LE) test, shear bond strength, compressive strength, and hydraulic bond strength (HBS). Our results indicate that CaO reactivity is a critical factor affecting the properties and performance of geopolymers for zonal isolation. Lower reactivities are associated with longer induction periods and lower heat evolution, which in turn increase LE. While lower reactivity decreases compressive strength, it increases shear bond strength. However, the CaO with the lowest reactivity resulted in a very low HBS due to matrix cracking and leakage. Therefore, optimizing the reactivity of CaO expansive agents is essential to enhancing the properties of geopolymer-based sealing materials for oil and gas wells. Shown in this paper is the successful application of CaO as an expansive agent for granite-based geopolymers at shallow depths in oil and gas wells.
- North America > United States (1.00)
- Europe (1.00)
- North America > Canada > Alberta (0.28)
- Research Report > New Finding (0.34)
- Overview (0.34)
- Well Drilling > Drilling Fluids and Materials > Drilling fluid selection and formulation (chemistry, properties) (1.00)
- Well Drilling > Casing and Cementing > Cement formulation (chemistry, properties) (1.00)
- Health, Safety, Environment & Sustainability > Environment (0.94)
- Well Completion > Well Integrity > Zonal isolation (0.82)
Sustained Annular Pressure Prevention in the Vaca Muerta Wells Optimizing Well Construction Through the Utilization of Metal Expandable Packers Technology
Torres, Jorge (YPF SA) | Calegari, Ricardo (YPF SA) | Arias, Fernando (YPF SA) | Arribillaga, Lucas (YPF SA) | López, Emiliano (Welltec) | Esquitin, Yosafat (Welltec) | López, José (Welltec) | Guilarte, Mariano (Welltec)
Abstract Drilling and completing oil and gas Wells into the unconventional Vaca Muerta Formation (Fm.) has proven to be a challenging task since the beginning of the development. The unique characteristics of the several formations oil operators must drill through in order to reach Vaca Muerta Fm along with the extended reach horizontal sections, make the complexity of the drilling operation to become a constant challenge for an optimized well architecture. To add up the extensive and demanding completions program, currently being executed with an average of 60 frac stages per well with a work pressure up to 13500 psi, make the construction of wells to be an even more challenging task. One of the main factors that make the previously describe scenario into an even more complex is the presence of Sustained Annular Pressure (SAP), this phenomenon affects around 35% of worldwide oil and gas wells (Farag, Mahmoud - 2015). This challenge represents several risks such as contamination of water formations, emission of greenhouse gasses, potential well blow outs. This situation it's been witnessed in some of the recently drilled well in the Vaca Muerta Fm, turning SAP into one of the challenges oil operators face today. Said phenomenon has been evidenced by the presence of pressure in the annular spaces at surface once the hydraulic fracturing programs have been completed. To mitigate SAP several alternatives to enhance or replaced the traditional cement seal are being evaluated; mechanical integrity of the cemented seal can be affected by the stresses generated in the casing as the frac operations gets developed, suffering multiple compression and expansion cycles. An effective and proven solution, that can be integrated into the well's completion program helping to achieve the prevention of SAP, is the Metal Expandable Packer (MEP) technology. This new technology can help mitigate SAP eliminating the need for complex remedial operations that usually increases the costs and operational risks. The following paper shows the process of technology selection, qualification, job planning, field deployment of MEP and results.
- North America (0.94)
- South America > Argentina > Neuquén Province > Neuquén (0.49)
- South America > Argentina > Patagonia > Neuquén > Neuquen Basin > Vaca Muerta Shale Formation (0.99)
- South America > Argentina > Patagonia > Neuquén > Neuquen Basin > Vaca Muerta Field > Vaca Muerta Shale Formation (0.98)