Montney Formation Field
ABSTRACT Distributed acoustic sensing (DAS) is a technology that enables continuous, real-time measurements along the entire length of a fiber-optic cable. The low-frequency band of DAS can be used to analyze hydraulic fracture geometry and growth. In this study, the low-frequency strain waterfall plots with their corresponding pumping curves were analyzed to obtain information on fracture azimuth, propagation speed, number of fractures created in each stage, and restimulation of preexisting fractures. We also use a simple geomechanical model to predict fracture growth rates while accounting for changes in treatment parameters. As expected, the hydraulic fractures principally propagate perpendicular to the treated well, that is, parallel to the direction of maximum horizontal stress. During many stages, multiple frac hits are visible, indicating that multiple parallel fractures are created and/or reopened. Secondary fractures deviate toward the heel of the well, likely due to the cumulative stress shadow caused by previous and current stages. The presence of heart-shaped tips reveals that some stress and/or material barrier is overcome by the hydraulic fracture. The lobes of the heart are best explained by the shear stresses at 45° angles from the fracture tip instead of the tensile stresses directly ahead of the tip. Antennas ahead of the fracture hits indicate the reopening of preexisting fractures. Tails in the waterfall plots provide information on the continued opening, closing, and interaction of the hydraulic fractures within the fracture domain and stage domain corridors. The analysis of the low-frequency DAS plots thus provides in-depth insights into the rock deformation and rock-fluid interaction processes occurring close to the observation well.
- North America > Canada > British Columbia > Western Canada Sedimentary Basin > Alberta Basin > Montney Formation Field > Montney Formation (0.99)
- North America > Canada > British Columbia > Western Canada Sedimentary Basin > Alberta Basin > Montney Formation (0.99)
- North America > Canada > Alberta > Western Canada Sedimentary Basin > Greater Peace River High Basin > Pouce Coupe Field (0.99)
- (2 more...)
- Well Drilling > Wellbore Design > Wellbore integrity (1.00)
- Well Completion > Hydraulic Fracturing (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Reservoir geomechanics (1.00)
- Production and Well Operations > Well & Reservoir Surveillance and Monitoring > Production logging (1.00)
A Comprehensive Review of Casing Deformation During Multi-Stage Hydraulic Fracturing in Unconventional Plays: Characterization, Diagnosis, Controlling Factors, Mitigation and Recovery Strategies
Uribe-Patino, J. A. (University of Alberta) | Casero, A. (bp) | Dall'Acqua, D. (Noetic Engineering) | Davis, E. (ConocoPhillips) | King, G. E. (GEK Engineering) | Singh, H. (CNPC USA) | Rylance, M. (IXL Oilfield Consulting) | Chalaturnyk, R. (University of Alberta) | Zambrano-Narvaez, G. (University of Alberta)
Abstract The objective of this paper is to provide a review of casing deformations that are related to the placement of Multi-Stage Hydraulic Fracturing (MSHF) in unconventional plays. This work aims to identify practical mitigation and management strategies to reduce the overall impact of such events on the economic outcome of any development. The methodology incorporates a comprehensive literature review and leverages insights from the authors’ extensive field experience. This approach aims to explore the current state of knowledge regarding casing deformations associated with MSHF in unconventional reservoirs across key global basins. This paper encompasses the identification, diagnostics, surveillance, and monitoring of such deformations as they manifest and progress, along with the implementation of mitigation and management strategies prior to and during the well-completion process. The authors recognize the disparity between the number of publications available and the actual incidence of casing deformation in specific basins and are conscious that obtaining an exact estimate may often be elusive. The technical aspects of the review rely on the examination of numerous case studies from various unconventional basins. This is achieved by establishing a comprehensive understanding of the potential causes and mechanisms of casing deformations, including their occurrence, detection, and identification. Subsequently, an analysis is performed that presents the inherent characteristics of the different types of casing deformation, encompassing their nature, severity, distribution, and frequency across the basins considered, their lateral locations, event occurrence, specific nature and other pertinent factors. Additionally, the review addresses the geological, geo-mechanical, engineering and operational control factors that are likely to contribute to such deformations. Furthermore, it identifies a range of potential mitigation strategies aimed at minimizing the occurrence and ultimately the economic effects of casing deformation occurrence. This review builds upon various ongoing industry technical initiatives undertaken by the SPE Well Integrity Technical Section - Casing Deformation Work Group. The study findings can potentially provide practical measures to manage and mitigate casing deformation in unconventional basins within horizontal wells, thus minimizing the associated economic impact. Remaining knowledge gaps that require consideration should be addressed by actively sharing best practices and case histories within the industry on a global scale. This collaborative review paper, involving operating companies and other experts, serves as an initial step in that direction, aiming to catalyse further discussion among professionals working in this sector. It is intended as a rallying cry to encourage broader participation, deeper and shared consideration of the considerable effects of casing deformation occurrence.
- North America > United States > Texas (1.00)
- North America > Canada > Alberta (1.00)
- Asia > Middle East (1.00)
- (5 more...)
- Geology > Structural Geology (1.00)
- Geology > Petroleum Play Type > Unconventional Play > Shale Play (1.00)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (0.50)
- South America > Argentina > Patagonia > Neuquén > Neuquen Basin > Vaca Muerta Shale Formation (0.99)
- Oceania > Australia > Northern Territory > McArthur Basin > Beetaloo Basin (0.99)
- North America > United States > Wyoming > Powder River Basin (0.99)
- (71 more...)
- Information Technology > Knowledge Management (0.46)
- Information Technology > Communications (0.46)
Practical Optimization of Perforation Design with a General Correlation for Proppant and Slurry Transport from the Wellbore
Dontsov, Egor (ResFrac Corporation, Palo Alto, CA, USA) | Ponners, Christopher (ResFrac Corporation, Palo Alto, CA, USA) | Torbert, Kevin (Cornerstone Engineering, Inc., Bakersfield, CA, USA) | McClure, Mark (ResFrac Corporation, Palo Alto, CA, USA)
Abstract During plug and perf completion, perforation pressure drop is used to encourage a uniform distribution of flow between clusters by overcoming stress shadowing, stress variability, and nonuniform breakdown pressure. However, proppant inertia, gravitational settling, and perforation erosion contribute to nonuniformity, even with an aggressive limited-entry design. In prior work, Dontsov (2023) developed a correlation for predicting proppant outflow from the wellbore as a function of slurry velocity, perforation phasing, and other parameters. In the present study, the Dontsov (2023) correlation is integrated into a wellbore dynamics simulator capturing key physical processes that control slurry and proppant outflow from the wellbore, such as erosion, stress shadowing, and near-wellbore tortuosity. The simulator is fast running and incorporated into a tool for Monte Carlo uncertainty quantification and design optimization. First, we run a series of sensitivity analysis simulations to evaluate the effect of key model inputs. The simulations demonstrate processes that can cause heel bias, toe bias, or heel/toe bias in the erosion distribution. Next, we apply the tool to analyze field datasets from the Eagle Ford and the Montney. Downhole imaging of erosion data enables model calibration. Calibration is necessary because differences in casing, cement, and formation properties cause differences in erosion behavior and flow distribution. Parameters controlling the magnitude of erosion and stress shadow are modified to match the trends observed from the downhole imaging. After calibration is performed, the model is applied to maximize the uniformity of proppant placement by optimizing perforation phasing, diameter, count, and cluster spacing.
- Geophysics > Seismic Surveying > Borehole Seismic Surveying (0.55)
- Geophysics > Borehole Geophysics (0.55)
- North America > United States > Texas > Permian Basin > Yeso Formation (0.99)
- North America > United States > Texas > Permian Basin > Yates Formation (0.99)
- North America > United States > Texas > Permian Basin > Wolfcamp Formation (0.99)
- (26 more...)
Distributed Acoustic Sensing (DAS) is a technology that enables continuous, real-time measurements along the entire length of a fiber optic cable. The low-frequency band of DAS can be used to analyze hydraulic fracture geometry and growth. In this study, the low-frequency strain waterfall plots with their corresponding pumping curves were analyzed to obtain information on fracture azimuth, propagation speed, number of fractures created in each stage, and re-stimulation of pre-existing fractures. We also use a simple geomechanical model to predict fracture growth rates while accounting for changes in treatment parameters. As expected, the hydraulic fractures principally propagate perpendicular to the treated well, that is, parallel to the direction of maximum horizontal stress. During many stages, multiple frac hits are visible indicating that multiple parallel fractures are created and/or re-opened. Secondary fractures deviate towards the heel of the well, likely due to the cumulative stress shadow caused by previous and current stages. The presence of heart-shaped tips reveals that some stress and/or material barrier is overcome by the hydraulic fracture. The lobes of the heart are best explained by the shear stresses at 45-degree angles from the fracture tip instead of the tensile stresses directly ahead of the tip. Antennas ahead of the fracture hits indicate the re-opening of pre-existing fractures. Tails in the waterfall plots provide information on the continued opening, closing, and interaction of the hydraulic fractures within the fracture domain and stage domain corridors. Analysis of the low-frequency DAS plots thus provides in-depth insights into the rock deformation and rock-fluid interaction processes occurring close to the observation well.
- North America > Canada > Alberta (1.00)
- North America > United States (0.67)
- North America > Canada > British Columbia > Western Canada Sedimentary Basin > Alberta Basin > Montney Formation Field > Montney Formation (0.99)
- North America > Canada > British Columbia > Western Canada Sedimentary Basin > Alberta Basin > Montney Formation (0.99)
- North America > Canada > Alberta > Western Canada Sedimentary Basin > Greater Peace River High Basin > Pouce Coupe Field (0.99)
- (2 more...)
- Well Drilling > Wellbore Design > Wellbore integrity (1.00)
- Well Completion > Hydraulic Fracturing (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Reservoir geomechanics (1.00)
- Production and Well Operations > Well & Reservoir Surveillance and Monitoring > Production logging (1.00)
Shale Gas Production Forecasting with Well Interference Based on Spatial-Temporal Graph Convolutional Network
Xu, Ziming (School of Mining & Petroleum Engineering, Department of Civil & Environmental Engineering University of Alberta, Edmonton, Alberta, Canada.) | Leung, Juliana Y. (School of Mining & Petroleum Engineering, Department of Civil & Environmental Engineering University of Alberta, Edmonton, Alberta, Canada.)
Abstract One of the core assumptions of most deep learning-based data-driven models is that samples are independent. However, this assumption poses a key challenge in production forecasting - performance is influenced by well interference and reservoir connectivity. Most shale gas wells are hydraulically fractured and exist in complex fracture systems, and the neighbouring well characteristics should also be considered when constructing data-driven forecast models. Researchers have explored using the Graph Convolutional Network (GCN) to address this issue by incorporating neighbouring well characteristics into production forecasting models. However, applying GCN to field-scale studies is problematic, as it requires training on a full batch, leading to gigantic cache allocation. Additionally, the transductive nature of GCN poses challenges for direct generalization to unseen nodes. To overcome these limitations, we adopt the Graph Sampling and Aggregation (GraphSAGE) network architecture, which allows training large graphs with mini-batches and generalizing predictions for previously unseen nodes. By cooperating with the Gated Recurrent Unit (GRU) network, the proposed Spatial-Temporal (ST)- GraphSAGE model can capture cross-time relationships between the target and the neighbouring wells and generate promising prediction time series for the target wells, even if they are newly drilled wells. The data set is based on field data corresponding to 2,240 Montney shale gas wells and consists of formation properties, fracture parameters, production history and operational data. The algorithm aggregates the first-hop information to the target node for each timestep. The Encoder-Decoder (ED) architecture is employed to generate forecasts for the subsequent three-year production rate by using the one-year production history of the wells. The trained model enables the evaluation of production predictions for newly developed wells at any location. We evaluate the model's performance using P10, P50, and P90 of the test dataset's Root Mean Square Error (RMSE). Our method preserves the topological characteristics of wells and generalizes the prediction to unseen nodes while significantly reducing training complexity, making it applicable to larger oil/gas fields. By incorporating information from adjacent wells and integrating spatial-temporal data, our ST-GraphSAGE model outperforms the traditional GRU-ED model and shows enhanced interpretability.
- North America > Canada > British Columbia > Western Canada Sedimentary Basin > Alberta Basin > Montney Formation Field > Montney Formation (0.99)
- North America > Canada > Alberta > Western Canada Sedimentary Basin > Alberta Basin > Montney Formation Field > Montney Formation (0.99)
Abstract In September 2021, the Alberta Energy Regulator (AER) through a new pressure and deliverability testing directive issued new guidance for inline testing to align with the current practice for conducting these tests. Best practices of these techniques are presented for calculations for industry-submitted inline testing for flowback analysis and industry-submitted Absolute Open Flow deliverability analysis. Results are compared to previously published best practices in the Canadian Unconventional Montney. The new approach is based on obtaining dynamic fracture dimensions such as fracture half-length and height, conductivity, associated matrix permeability, and well productivity index estimates. This information is supporting evaluation on reserves and near wellbore communication. Analytical and numerical method descriptions are provided that has proven to have significant implications for treatment stage design and reservoir characterization. Complete governing equations are provided and flowback and deliverability techniques are described in detail to permit readers to replicate all results. 80 field case studies are presented for multi-stage hydraulic fractured horizontal wells in the Canadian Unconventional Montney. Comparisons are also provided for Inline testing and deliverability- derived productivity index. The most significant new findings are the variability of fracture dimensions, conductivity, matrix permeability and productivity index impacting reservoir characterization. This is important for well spacing and bench-related reserves assessment at the pad level. For AER it also means an enhancement on reserves assessment of the Montney for its flagship report ST-98 by conducting Rate Transient Analysis (RTA) using rate and bottom-hole pressure information. The findings have direct practical implications for operators in the Canadian Montney shale play and analogous shale plays in USA and elsewhere. Accurate production and pressure data is needed for calculating linear flow parameters, effective surface area, fracture length / height and for optimizing well spacing and frac design. It could be used for input for Rate Transient Analysis (RTA) for resources / reserves assessments in similar unconventional plays. The novelty of the new approach is in the ability to develop best practices in inline testing and analysis in the Canadian unconventional Montney, focus of significant short-term investment impacting royalties and solve non-uniqueness and/or uncertainty for well testing / completions/ production / reserves in reasonable time using the newly aligned engineering processes.
- North America > United States (1.00)
- North America > Canada > British Columbia (1.00)
- North America > Canada > Alberta (1.00)
- Research Report > New Finding (0.66)
- Overview (0.54)
- North America > United States > West Virginia > Appalachian Basin > Marcellus Shale Formation (0.99)
- North America > United States > Virginia > Appalachian Basin > Marcellus Shale Formation (0.99)
- North America > United States > Texas > West Gulf Coast Tertiary Basin > Eagle Ford Shale Formation (0.99)
- (16 more...)
Abstract Current practice for conducting minifrac or diagnostic fracture injection tests has been changing with time. The Alberta Energy Regulator (AER) has a pressure and deliverability testing directive that has guidance on those tests. This guidance was updated in late 2021. Many operators from the Canadian Montney shale play submit minifracs to AER, 80 of these minifracs were summarized statistically in this paper. Closure, reservoir pressure, and permeability were the main analyzed parameters in the paper scope. Requirements for pressure and deliverability tests are set out by this newly updated directive. Industry uses minifrac in horizontal wells with multistage fracture treatments when developing unconventional reservoirs. Closure, initial reservoir pressure is commonly being determined with the common well test. Holistic or tangent vs. compliance method are compared for closure pressure in this paper. Readers are eager to replicate results, so for After Closure Analysis (ACA) methods equations that govern the analysis are provided in detail. Published or commercially available holistic and compliance models are compared for closure pressure. Published or commercially available ACA Soliman and Nolte methods are compared for permeability and reservoir pressure. Horizontal wells in 80 unconventional shale field case studies are presented. The fact that the signature of closure pressure is not apparent is a significant finding. Similarity of closure pressure outcomes or estimates for tangent vs compliance is remarkable. Differentiation of reservoir pressure determination for either linear or radial flow are observed. Interpretation on net pressure impact is evaluated and ultimately differentiation on ACA permeability determination is assessed. Analogous shale plays operators in USA and current Canadian Montney Shale play operators will find practical and direct implications. To calculate effective fracture half length and optimize fracture design and well spacing accurate permeability values are needed. To design hydraulic fractures with geomechanics applications accurate closure pressure values are essential. To conduct Rate Transient Analysis (RTA) for resources and reserves assessment in similar unconventional shale plays accurate initial reservoir pressure as an input is fundamental. Comparing analytically closure pressure methods in unconventional shale plays is novel. In addition, practicing engineers or well testing interpreters will find the comparison of different after closure analysis relevant.
- North America > Canada > British Columbia (1.00)
- North America > Canada > Alberta (1.00)
- Geology > Petroleum Play Type > Unconventional Play > Shale Play (1.00)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock (0.34)
- North America > Canada > British Columbia > Western Canada Sedimentary Basin > Alberta Basin > Montney Formation Field > Montney Formation (0.99)
- North America > Canada > British Columbia > Western Canada Sedimentary Basin > Alberta Basin > Montney Formation (0.99)
- North America > Canada > Alberta > Western Canada Sedimentary Basin > Alberta Basin > Montney Formation Field > Montney Formation (0.99)
- (2 more...)
Understanding Shale Fracture Network Complexity in the Laboratory
Abdelaziz, Aly (University of Toronto, Canada) | Wu, Phyllis S. (University of Toronto, Canada) | Li, Mei (University of Toronto, Canada) | Magsipoc, Earl (University of Toronto, Canada) | Peterson, Karl (University of Toronto, Canada) | Grasselli, Giovanni (University of Toronto, Canada)
ABSTRACT: Hydraulic fracturing is a complex multi-physics process that involves coupling of fluid flow and rock deformation/fracturing. Particularly, the propagation of fluid-driven fractures is a competing process greatly influenced by rock fabric and in-situ stress. However, it remains unclear how rock fabric affects the failure mechanisms and contributes to the resulting fracture network. To understand this, an 80 mm Montney shale outcrop cube was hydraulically fractured in the laboratory under in-situ true triaxial stress conditions. The fractured sample was then digitally 3D reconstructed by merging high-resolution, high-contrast serial section images. In-depth observation of the digitally-reconstructed induced fracture-network revealed the formation of bedding-controlled horizontal fractures, opening against σ2 instead of the theoretically expected σ3. This suggests the key role played by the bedding planes in determining the trajectory of the fluid-driven fracture network. En-echelon fractures observed near the injection borehole are convincing evidence of possible shear failures associated with hydraulic fracturing. INTRODUCTION Since its first adoption as "Hydrafrac" process in 1947 (Clark 1949), hydraulic fracturing has revolutionized oil and gas extraction operations and became the key technology that has allowed to unlock those low permeability resources that have been developed for the past twenty years (Keshavarz et al. 2018). Irrespective of the completion method (open hole, plug and perf, or sliding sleeve), the ultimate goal for hydraulic fracturing is to achieve an optimized fracture geometry that maximizes the stimulated rock volume (SRV) and thus enhances production. The first fundamentals behind hydraulic fracturing date back to Hubbert and Willis 1957, who considered a normal faulting system with the maximum (σH) and minimum horizontal (σh) stresses acting perpendicular to the vertical wellbore. However, they overlooked the strength of the rock mass in tension presuming it "a notoriously undependable quantity" and to be "reduced to zero" at depth due to its intersection with one or more open joint system. Regardless, the conditions associated with their work was very constrictive and most analytical equations thereafter consider a vertical hole where the horizontal stresses acting on the hole are either in a normal fault regime, i.e., σH and σh act perpendicular to the trajectory of the hole or that a reverse/thrust fault regime is being fractured where σh is the least principal stress (σ3). In both cases, fracture initiation and propagation would occur perpendicular to σ3 at breakdown pressures equal to or less than the vertical overburden pressure (σv). The fracture trajectory would be vertical to the hole cross section in the normal faulting regime and horizontal in the reverse/thrust fault regime. In the event the breakdown pressure is greater than σv, the pressure parting phenomenon is also possible. This phenomenon signifies rock rupture, i.e., failure due to injection of fluid into a bedding plane, joint, or other structural weaknesses (Torrey 1951). This phenomenon is recognized in well acidizing operations (Clark 1949; Torrey 1951) and is characterized by a fracture that extends rapidly and for considerable distance away from the injection hole.
- North America > Canada > Alberta (0.67)
- North America > Canada > Ontario > Toronto (0.17)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Structural Geology > Fault > Dip-Slip Fault > Normal Fault (0.89)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (0.73)
- Geology > Structural Geology > Fault > Dip-Slip Fault > Reverse Fault > Thrust Fault (0.45)
- North America > Canada > British Columbia > Western Canada Sedimentary Basin > Alberta Basin > Montney Formation Field > Montney Formation (0.99)
- North America > Canada > Alberta > Western Canada Sedimentary Basin > Alberta Basin > Montney Formation Field > Montney Formation (0.99)
- Well Completion > Hydraulic Fracturing (1.00)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Shale gas (1.00)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Naturally-fractured reservoirs (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Reservoir geomechanics (1.00)
Private Canadian oil company Strathcona Resources announced this week its intent to acquire smaller producer Pipestone Energy in an all-stock transaction. Strathcona said upon closing it will move to become a publicly traded company with a market capitalization of nearly 6.5 billion. On a pro forma basis, the deal creates the fifth-largest oil and gas producer in Canada as a measure of liquids production and proved reserves. The combined company will boast 185,000 BOE/D (152,000 BOE/D from Strathcona; 35,000 BOE/D from Pipestone), 70% of which is reported as crude and gas condensate. The combined portfolio includes the Cold Lake thermal project (55,000 BOED), Lloydminster heavy-oil project (55,000 BOE/D), and operations in the Montney (75,000 BOE/D).
- North America > Canada > British Columbia > Western Canada Sedimentary Basin > Alberta Basin > Montney Formation Field > Montney Formation (0.99)
- North America > Canada > Alberta > Western Canada Sedimentary Basin > Alberta Basin > Montney Formation Field > Montney Formation (0.99)
The 3rd International Geomechanics Symposium (IGS2022) took place 7–10 November 2022 in Abu Dhabi. Focusing on the role of geomechanics in energy efficiency and sustainability, the technical program covered a range of technology applications including rock and in-situ stress characterization, natural fractures, faults, drilling, completion, stimulation, production, and reservoir engineering. It also showcased geomechanics applications in CO2 sequestration, hydrogen storage, and new energies.
- North America > United States (1.00)
- Asia > Middle East > Saudi Arabia (0.61)
- Asia > Middle East > UAE > Abu Dhabi Emirate > Abu Dhabi (0.27)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock (0.96)
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > Asia Government > Middle East Government (0.62)
- North America > Canada > British Columbia > Western Canada Sedimentary Basin > Alberta Basin > Montney Formation Field > Montney Formation (0.99)
- North America > Canada > Alberta > Western Canada Sedimentary Basin > Alberta Basin > Montney Formation Field > Montney Formation (0.99)
- Asia > Middle East > Iraq > Basra Governorate > Arabian Basin > Widyan Basin > Mesopotamian Basin > Rumaila Field > Zubair Formation (0.99)
- (4 more...)