Day 2 Wed, February 01, 2023最新文献

{"title":"One Shot Wonder XLE Design: A Continuous Improvement Case Study of Developing XLE Design in the Bakken","authors":"A. Lorwongngam, Michael G. McKimmy, E. Oughton, C. Cipolla","doi":"10.2118/212358-ms","DOIUrl":"https://doi.org/10.2118/212358-ms","url":null,"abstract":"Many operators have been working on optimizing stage spacing or clusters per stage to maximize production and reduce completion capital investment in unconventional wells. The operator has successfully proved that eXtreme Limited Entry (XLE) design works well in the Bakken. This paper uses a continuous improvement concept to improve on the paper presented in 2020 URTeC: 2796. The objective of this study is to push the boundary of perforation design that has been used as a standard design since 2020 to evaluate the optimum Shots Per Cluster (SPC), the minimum Rate Per Cluster (RPC), and the maximum Clusters Per Stage (CPS) that can still further maximize well production and provide optimum fracture cluster efficiency and Uniformity Index (UI). This paper will also address the comparison between XLE design and other diversion techniques. Through the 3-year journey of understanding and optimizing XLE design, the operator had a total of 4 pads planned as a part of this study. The first 2 pads used to prove the XLE design concept utilized Radio Active (RA) tracer, deployable fiber optic, step down tests, downhole camera, perforation acoustic imaging tool, and production data. The other 2 pads are the observation lateral project [Cipolla et al. 2022] and a permanent fiber project; both projects include lateral bottom hole gauges, offset well fiber optic strain, and permanent fiber along the lateral. This paper uses part of the data from these projects to help validate fracture morphology, rate per cluster, and maximum clusters per stage. The operator uses the Lean continuous improvement and plan-do-check-adjust process to work from the planning to the standardization of the design. RA tracer, step-down test, and deployable fiber optic results show that XLE with 1 Shot Per Foot (SPF) yields high production cluster efficiency of more than 90%, high uniformity index, and comparable production data to the non-XLE design while lowering the completions cost. From the permanent fiber optic data, the results show that the minimum rate per cluster to yield a uniformity index of more than 80% in the Bakken is ~ 5 BPM for 4-1/2\" liner and ~6 BPM for 5-1/2\" liner. Using a continuous improvement process, the operator adopted the XLE design with 1 SPF as the current completion design standard. This design is proven to yield high productivity and increase asset value by lowering the cost of completions by more than 12%. In the high oil price environment, the XLE design can also be used to maximize asset value by increasing entry points in the well. This leads to an increase in short-term production. Throughout the data gathering and trial process, the operator also gathered novel pressure data allowing for direct measurement of perforation friction, and near-wellbore friction Limited Entry and Extreme Limited Entry Designs","PeriodicalId":402242,"journal":{"name":"Day 2 Wed, February 01, 2023","volume":"10 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-01-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"123808035","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"The Effect of Casing Deformation on Frac Plug Sealing Element Performance","authors":"Hiroaki Yoshida, S. Jafri, M. Okura, Shinya Takahashi, W. Li","doi":"10.2118/212377-ms","DOIUrl":"https://doi.org/10.2118/212377-ms","url":null,"abstract":"\u0000 Sealing element of frac plugs have crucial roles to isolate target zones of the well in hydraulic fracturing. If the zonal isolation by the sealing element is not adequate, it can result in erosion of the casing. The effect of casing deformation on sealing performance of sealing element is not well researched or understood. To study the effect of casing deformation on sealing performance, finite element analysis of sealing element in deformed casing was conducted in this study to assess the effect of casing deformation on sealing performance. In this study, finite element simulation of a full frac plug with three different casings ovalities (0%, 2%, and 5%) and three different sealing element designs (O-ring type, short type, traditional long type) was conducted to evaluate deformation behavior and sealing performance of the sealing elements in the deformed casings. Compression pressure on the casing by sealing element after the plug is set in the casing and the risk of leak were discussed and compared for each design. In the casing with 0% ovality, all the sealing element designs established contact with inner surface of the casing when setting force is applied. However, for the O-ring type design, 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 deformation and ovality in the casing, the minor ID has a smaller ID and a major ID has a larger ID compared to nominal ID of the casing. In the casing with 2% and 5% ovality, neither O-ring type nor short type sealing element could contact the major ID of the casing and there was a gap between inner surface of the casing and the sealing element. This gap can cause erosion of the frac plugs and casing when fluid passes through the gap. In contrast, traditional long type sealing element 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 condition if frac plugs with small sealing element is used. Since there are various types of frac plugs with different sealing element designs, this study helps to select proper frac plugs with good sealing element design and mitigate the risk of erosion of casings and plugs.","PeriodicalId":402242,"journal":{"name":"Day 2 Wed, February 01, 2023","volume":"47 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-01-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"122131426","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Production and Hydraulic Fracturing Design Optimization in the Presence of Natural Fractures, Clair Field","authors":"Anastasia Bird, A. Casero, Laryssa Ligocki, Claudia Parada-Machado, James Hoad, V. Sesetty","doi":"10.2118/212356-ms","DOIUrl":"https://doi.org/10.2118/212356-ms","url":null,"abstract":"\u0000 The Clair field could be described as an ‘unconventional’ conventional reservoir. The rock matrix permeability places reservoir into the conventional category, for which conventional fracturing design in terms of high proppant concentration and fracture conductivity are required for production uplift. However, the presence of natural fractures brings the Clair field a similarity to unconventional reservoirs where impact and contribution of natural fractures must be taken into the equation.\u0000 This paper describes the integrated fracturing and production optimization study that was conducted to optimize multistage hydraulic fracturing design in the presence of natural fractures of various density in the Clair field. The production uplift of hydraulic fracturing in conventional reservoirs is well understood. However, the presence of natural fractures adds an unconventional twist of complexity and uncertainty to fracturing design and even more so to production uplift estimates.\u0000 To reduce the uncertainty of hydraulic fracturing uplift in the presence of natural fractures, specialized software was used to explicitly model cases with a range of density discrete fracture networks (DFNs) and the interaction with hydraulic fractures. Then the resulting fracture geometries were input into production modelling software to estimate uplift and calibrated back to producers in the segment. This process was repeated for several reservoir scenarios and fracturing designs to establish the production uplift range and ultimately inform optimal hydraulic fracturing design recommendations.\u0000 One of the most valuable, yet not most intuitive observations was that the natural fractures and the hydraulic fractures can have a synergistic effect on production. All DFN cases modelled showed benefit from using hydraulic fracturing including high density DFNs. Even when natural fractures are already present, hydraulic fractures will help in connecting the natural fractures to the well and increase production. Higher numbers of hydraulic fractures were associated with the best uplift predictions. The described work has been instrumental in changing how hydraulic fracturing is being considered for naturally fractured reservoirs in general and for the Clair field in particular. Hydraulic fracturing had originally just been seen as a mitigation to a poorly fractured (low/no DFN) outcome. With the results of this study however it is evident that hydraulic fracturing is also an enabler for increased production in a wide range of DFN cases. Several practical recommendations have resulted from this study such as multistage fracture spacing, number of fractures, optimized proppant placement between stages and fracture geometry. The impact of fracture vs wellbore orientation and overflush were also modelled.\u0000 This is the first time such a workflow has been applied for a conventional yet naturally fractured reservoir. The proposed modelling workflow allows for optimization and robust fra","PeriodicalId":402242,"journal":{"name":"Day 2 Wed, February 01, 2023","volume":"14 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-01-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"134438281","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Overflush and Fracturing: Playing Poker with your Completion","authors":"M. Rylance","doi":"10.2118/212342-ms","DOIUrl":"https://doi.org/10.2118/212342-ms","url":null,"abstract":"\u0000 Since the inception of hydraulic fracturing, the industry has wrestled with the concept of over/under- flushing, and has always pitched this as a binary philosophy, attempting to determine/define that this is either a fundamentally good or a bad approach. This schism simply grew with the extensive development of unconventionals; the use of overflush being an inherent and fundamental requirement for an effective and economic unconventional completion sequence. This paper will demonstrate that the true answer, as any engineer would expect, is that a detailed assessment is what is required and on a case-by-case basis.\u0000 The paper will describe and reference several fracturing case histories, in both the Conventional and Unconventional environments, where the application of an overflush, an underflush or an engineered approach have been assessed or applied. Rather than taking an easy headline grabbing route to perpetuate the myth that the process is a major paradigm, or simply either a good or a bad thing. This paper will discuss some of the key aspects that impact the suitability of one approach over another; and how engineering the implementation can lead to a broader range of applicability/suitability for the most economically effective outcome. This includes an appreciation of the production/economic profile and exposure to risk, which is hugely different in say an ultra-deep-water five well offshore development vs. a field development with some 100s – 1,000s of wells in a lower-cost onshore environment.\u0000 The paper will describe and demonstrate some of the fundamental variables that need to be considered; attempting to elaborate on a few of the key parameters which can influence the effective outcome. The paper will also indicate that there are several different scenarios whereby any form of overflush can result in a detrimental impact on the production rate and EUR, and that these must be fully appreciated. Subtleties, related to reservoir characteristics and fracture geometry; should be examined and appreciated. Additional aspects such as how the production, drawdown and pore-pressure will be managed can also have an impact. All these considerations, and more, will be discussed, described, and referenced.\u0000 While there is no doubt that the overflush debate will continue unabated, the intent of this paper is to reduce the damage (or uncertainty), one way or the other, that will result. It is an attempt, at a minimum, to ensure that the debate becomes solely a technical one related to the approaches to be taken rather than a black and white one of right or wrong. Ultimately, the paper will advise, and inform, that the approach should be fully considered, engineered in detail and tailored to each and every application and that as a result is no longer simply considered a binary question.","PeriodicalId":402242,"journal":{"name":"Day 2 Wed, February 01, 2023","volume":"695 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-01-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"121231824","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"A Hybrid Data-Driven/Physics-Based Approach for Near-Wellbore Hydraulic Fracture Modeling","authors":"Andreas Michael","doi":"10.2118/212355-ms","DOIUrl":"https://doi.org/10.2118/212355-ms","url":null,"abstract":"\u0000 Variables affecting the near-wellbore region of a fractured well have a big impact on its post-stimulation well performance. Optimal hydraulic fracture (HF) initiation and early-phase propagation results in minimal near-wellbore tortuosity, decreasing the likelihood of screenouts and maximizing the resultant well productivity. While most predictive models for the HF geometry produced in a stimulation treatment consider the far-field region, the near-wellbore vicinity should be an integral part of a properly-engineered reservoir exploitation strategy, impacting the treatment's design and execution. In this work, a hybrid data-driven/physics-based approach is elaborated for modeling HF initiation and early-phase propagation from perforated horizontal wells.\u0000 An optimization scheme via oriented perforating is presented using the developed hybrid model, considering the orientation of the induced HF initiation (longitudinal or transverse with respect to a well drilled along the minimum horizontal in-situ principal stress) and the resultant formation breakdown pressure (FBP); the highest the wellbore pressure reached during the treatment. Transverse HF initiation (and early-phase propagation) is ideal for wells drilled in low-permeability \"tight\" formations, while FBP minimization decreases the overall on-site horsepower requirements for the stimulation treatment. The demonstrated optimization scheme is applied separately to the in-situ stress states of seven prolific shale plays from the U.S. and Argentina, suggesting oriented-perforating strategies targeting the promotion of transverse HF initiation in two of these (Barnett and Marcellus), while targeting FBP minimization in the remaining five (Bakken, Fayetteville, Haynesville, Niobrara, and Vaca Muerta). The effectiveness of such oriented-perforating strategies can potentially be compromised by fracturing fluid leakage around the borehole's circumference, which is shown to hinder transverse HF initiation.\u0000 The hybrid model is also used to estimate fracture initiation pressure (FIP) values for the seven shale plays studied, indicating significant discrepancies with analytical expressions used to approximate these FIPs in modern-day HF computational simulations. Finally, the framework is set for expanding this modeling approach over a range of in-situ stress states, incorporating data-driven (numerically-derived) aggregate correction factors to compensate for inaccuracies in the analytical approximations, which comprise the physics-based core of the proposed hybrid model. The impact of perforation geometry was not addressed in this study.","PeriodicalId":402242,"journal":{"name":"Day 2 Wed, February 01, 2023","volume":"4 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-01-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"126212737","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Initial Observations From a Bakken Microproppant Field Trial","authors":"T. Palisch, A. Lorwongngam, L. Kalfayan, Jon Giesbrecht","doi":"10.2118/212341-ms","DOIUrl":"https://doi.org/10.2118/212341-ms","url":null,"abstract":"\u0000 The Bakken production system is well established as a premier oil producing basin. Over the last 20 years improvements in drilling and completion designs have led to significant improvements in well productivity and increased EUR. One recent design change has been the incorporation of microproppant in the fracture design, which was deployed in a multi-well field study and shown to improve production, and is the subject of this paper.\u0000 As the industry continued to move to smaller size proppant, microproppants have been introduced as another potential improvement in the fracture design, supplementing the benefits of 100 mesh sand. It is theorized that microproppant can provide two primary benefits to well productivity – propping open microfractures, which reduces the production decline, and assisting in the breakdown of the perforations, thereby improving cluster efficiency. Production improvement has been documented in various basins across North America, leading one operator to design and implement a multi-well field trial to evaluate the production impact of microproppant in their Bakken completions.\u0000 This paper will provide a brief overview of microproppant technology and recent deployments across other basins, illustrating both productivity improvement as well as enhanced proppant placement. It will then focus on the multi-well field study performed in the Bakken in late 2021. In this trial, seven wells included the use of microproppant and are compared to 13 offset wells which deployed a comparable completion design, but without the microproppant. In the study area, the lateral lengths and proppant deployed per foot of lateral were held constant, and the wells/results are segregated between the Middle Bakken and Three Forks benches. To date, wells deploying microproppant show an average overall production uplift sufficient for the operator to pursue a larger scale field trial. This paper will discuss the completion design including details on how the microproppant was deployed. It will also include the general, initial production comparison between the trial and control wells.\u0000 This paper will continue to challenge engineers thinking on the role of proppant and how to best engineer the completion and fracture design to maximize recovery and return on investment. It will review a field study deploying the use of microproppant, as well as the design details, making it beneficial for completion engineers who desire to deploy microproppant. It will also be valuable for reservoir engineers searching for ways to improve cluster efficiency and overall hydrocarbon recovery.","PeriodicalId":402242,"journal":{"name":"Day 2 Wed, February 01, 2023","volume":"64 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-01-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"131886870","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Analysis of Shut-in Pressure Decline for Enhancing our Evaluation of Hydraulic Fracturing Treatments","authors":"A. Daneshy","doi":"10.2118/212317-ms","DOIUrl":"https://doi.org/10.2118/212317-ms","url":null,"abstract":"\u0000 The focus of this paper is on the analysis of shut-in data immediately after a fracturing treatment and critical information that can be learnt about the created fracture from the magnitude and rate of pressure decline during this period. The selected example data in this paper had two specific features; frac job was injected in two cycles in several stages, and had long shut-in time (more than 10 hrs) in all stages. Review of this data shows that frac growth in each stage continues at a decreasing rate beyond the end of pumping and how many hours of shut-in was needed for the fracture to reach its ultimate stable condition. In this horizontal well with multiple fractures the data also gives direct measure of the relative complexity of the created fractures in each stage and their conductivity.\u0000 The paper recommends specific practices that can enhance what can be learnt from the data. These include recording the pressure data continuously during the treatment and for the entire shut-in period, and occasional injection of a small volume of fluid into one or more randomly selected fracture stages to gain better understanding of fracture growth during the stage.\u0000 An important conclusion of the paper is that the Instantaneous Shut-In Pressure (ISIP) does not provide a reasonably accurate measure of the least in-situ principal within the fractured formation.","PeriodicalId":402242,"journal":{"name":"Day 2 Wed, February 01, 2023","volume":"48 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-01-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"115361067","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"A Catalogue of Fiber Optics Strain-Rate Fracture Driven Interactions","authors":"G. Ugueto, Kan Wu, G. Jin, Zhishuai Zhang, J. Haffener, Shahri Mojtaba, D. Ratcliff, Rob Bohn, A. Chavarria, Yinghui Wu, A. Guzik, Aishwarya Srinivasan, R. Gibson, A. Savitski","doi":"10.2118/212370-ms","DOIUrl":"https://doi.org/10.2118/212370-ms","url":null,"abstract":"\u0000 The downhole monitoring of strain using Fiber Optics (FO) can reveal unique information about the propagation and geometry of hydraulic fractures between nearby wells during stimulation and production. This work aims at creating a catalogue of commonly observed strain-rate signals captured in a not yet stimulated nearby observation well equipped with either a permanently or temporarily installed FO cable. This catalogue is the result of an informal collaboration between experience FO users from academia, service providers, consulting companies, and operators.\u0000 In the creation of this first edition of a strain-rate catalogue, we considered two main types of stimulation categories (single and multi-entry) as well as the angle between the hydraulic fractures and the segment of the well where the strain-rate signals are observed (horizontal vs. vertical segments). In the catalogue we show a series of representative examples of two main types of far-field strain Fracture Driven Interactions (s-FDI) commonly encountered in frac diagnostics: 1. Vertical hydraulic fractures being monitored in a lateral portion of a horizontal well and 2. Vertical fractures being monitored in a vertical observation well. The catalogue is organized around commonly observed s-FDI motifs. Because interpretation of observed strain-rate signals can be subjective, when possible, we included observed examples with a brief description of our interpretation, as well as synthetic signals from geomechanical models of similar motifs. The strain-rate motifs were modeled based on first physical principles for rock deformation. These models serve to support the proposed interpretation of the observed signals.\u0000 FO strain rate monitoring is changing our understanding about the hydraulics fracturing process. The information from FO strain is not available by other commonly used fracture diagnostic techniques. Strain- rate fractures driven interactions between wells occur in predictable patterns (Frac Domain and Stage Domain Corridors – FDC & SDC respectively) which are typically in line with the cluster spacing and stage length in the borehole being stimulated. Using FO strain monitoring, we now know that hydraulic fractures are larger than first anticipated, both in length and height. Many examples indicated that there is a direct correspondence between the near-field and far-field stimulation geometries. The lack of isolation due to cement quality and or plug failure manifests in the far-field geometries observed via FO strain-rate in nearby wells. The use of FO strain monitoring has also revealed that reopening of hydraulic fractures is common not only between prior and infill wells but also between wells from the same stimulation vintage. All these observations and conditions must be considered when interpreting new strain-rate datasets and more importantly when designing new hydraulic fracturing operations and considering different stimulation order (zipper schedule), as well as whe","PeriodicalId":402242,"journal":{"name":"Day 2 Wed, February 01, 2023","volume":"42 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-01-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"121822407","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}