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Have an idea for a technical paper? You may submit paper proposals for any of the following conferences. All proposals received will be evaluated by the Program Committee for the event. SPE must comply with all applicable sanction laws, including those of the United States and the United Kingdom. This includes screening individuals and entities against applicable lists of restricted parties to determine whether SPE is prohibited from, among other things, providing services to or receiving services from such parties.
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- North America > United States (0.89)
- Europe > United Kingdom (0.89)
Although many measurements are taken while fracturing, the term MWF refers to nonintrusive measurements taken on surface without fracturing operations interruption. MWF is characterized by enhanced event detectability and higher reflection depth determination accuracy. These are achieved by a combination of advanced signal processing algorithms and a tube wave velocity model based on Bayesian statistics, where each new signal is used as posterior information for decreasing uncertainty. Hammer union pressure transmitter with full scale pressure range (0 - 20K psi) is used to conduct measurements of pressure at wellhead. Device supports transfer of high-frequency pressure data from transmitter to monitoring software.
- North America > United States > Texas (1.00)
- Asia > Middle East > UAE > Abu Dhabi Emirate > Abu Dhabi (0.16)
- North America > United States > Texas > West Gulf Coast Tertiary Basin > Eagle Ford Shale Formation (0.99)
- North America > United States > Texas > Sabinas - Rio Grande Basin > Eagle Ford Shale Formation (0.99)
- North America > United States > Texas > Maverick Basin > Eagle Ford Shale Formation (0.99)
- (3 more...)
- Information Technology > Communications > Collaboration (0.40)
- Information Technology > Communications > Networks (0.36)
Unconventional Reservoirs: Contact Area and Fracture Network Resulting from Perforations in Shale. A Comparative Study of Different Shale Targets and Shaped Charge Designs Optimized for Hydraulic Fracturing
Loehken, J. (DynaEnergetics Europe GmbH, Troisdorf, Germany) | McNelis, L. (DynaEnergetics Europe GmbH, Troisdorf, Germany) | Yosefnejad, D. (DynaEnergetics Europe GmbH, Troisdorf, Germany) | Will, D. (DynaEnergetics Europe GmbH, Troisdorf, Germany)
Abstract After decades of a continuous improvement of the plug and perf technology for horizontal wells and especially the shaped charges employed, operators nowadays have the choice between a variety of shaped charge designs. As a guidance to choose the optimal charge, this snapshot examines the influence of shale rock type and shaped charge design on the tunnel created in the reservoir rock during perforation. Tests were conducted in an API Section II Test environment, simulating in-situ downhole conditions. Specifically, the investigation focused on the characteristics of the contact surface and the induced fracture network resulting from different perforation charges, each with its own distinctive tunnel geometry. Three different shaped charge designs were tested on various shale targets. This included equal entrance hole charges, maximum formation contact, and oriented perforation tailored charges. To assess the impact of the formation rock on the results, test shots were made on Marcellus, Mancos, and Lotharheiler, which is similar to the Haynesville or Eagle Ford, shale cores. The analysis included CT scans to identify tip fractures and to examine the shape of the tunnel as well as conventional core analysis. Additionally, newly formed fractures within the rock and on the surface of the perforation tunnel were identified. The test results indicate that both the charge type and the rock type significantly influence the tunnel geometry and fracture network. Although all charges created roughly the same entrance hole diameter in the casing, variations in tunnel length and contact surface as well as in the newly created fractures were observed. Notably, the shape of the tunnel deviated strongly from the theoretical assumed cylindrical or conical tunnel. Doglegs, as well as cavities were detected at many tunnel tips, which change the overall stress field at the tunnel wall. To determine which rock parameters are relevant, the cores underwent analysis in an external laboratory to assess their petrophysical properties for further correlation analysis. From a practical perspective shale rock proved to be a challenging target rock due to its high anisotropy and significant differences in rock strength between targets of the same formation. Additionally, the target cores were prone to cracking during the rock preparation process. Therefore, this study should be considered as a snapshot and conclusions drawn from this set of tests should be approached cautiously and account for these circumstances. Our study provides insights into the dependency of the perforation result on the type of shale and charge design. Depending on the combination of the perforation technique and the characteristics of the rock formation, distinct fracture networks and tip deviations are formed. This improved understanding will help to identify the best perforation strategy tailored to the specific reservoir rock's unique properties.
- North America > United States > Texas (1.00)
- Europe (1.00)
- 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)
- (18 more...)
Abstract The use of synthetic high viscosity friction reducers (HVFRs) has become common practice in hydraulic fracturing as a reliable method for delivering proppant into target formations. HVFRs address many of the challenges that are present when using cross-linked or linear gels and provide reliable performance across a wide range of water qualities. Despite these advantages, HVFRs present their own difficulties that must be addressed. The use of oxidizing or enzymatic breakers is essential when cross-linked gels are used for proppant transport to reduce the fluid's viscosity to a point where formation pressure is sufficient to allow the well to produce, and to minimize formation damage. While HVFRs are not nearly as viscous as cross-linked gels, they have sufficient molecular weight and are viscous enough, and persistent enough, to negatively impact flowback when a well is brought online. Moreover, it has been found that synthetic polymers can also cause serious formation damage similar to or worse than gel-based systems resulting in negative effects on the well's production. As a result, breakers are also commonly used in conjunction with HVFRs to maximize production of the well after stimulation is complete. It is difficult to know if these treatments are effective, however, and are largely guided by prior experience. Such reliance can be dangerous, however, given that HVFRs can comprise a wide range of chemical compositions, molecular weights, and physical forms. We believe a more systematic study of breaker effects on HVFRs is warranted to develop a better understanding of how combinations of breakers and HVFRs should be applied in field operations. Here we will discuss a series of laboratory investigations conducted to understand how different types of HVFRs respond to treatment with various breakers. The breakers selected are chemically distinct and may operate via different mechanisms (e.g., oxidative, non-oxidative), or on different timescales (e.g., instantaneous, slow release). Likewise, the HVFRs are comprised of distinct polymer backbones, and thus we anticipate will behave differently when exposed to the breakers. Indeed, significant differences in viscosity reduction behavior are observed depending on the HVFR-breaker pairing, concentrations of the two components, and test temperature. Some findings were unsurprising, such as the broad applicability and rapid response of instantaneous oxidative breakers, while others were not, such as the relatively selective and temperature-dependent response of non-oxidative breakers. Such a diversity of breaker chemistries and response behavior may initially seem overwhelming for completion engineers designing a stimulation pump schedule. However, we believe that this diversity may, in fact, present an opportunity for more nuanced treatments (i.e., break profiles) through judicious selection and application of breaker and HVFR combinations, all within the context of a well's characteristic temperature and water chemistry.
Abstract Improving cluster efficiency is critical for economic and efficient multi-cluster per stage fracturing in unconventional shale & tight horizontal well completion. This paper highlights the findings from a field trial to test different perforation design variables which contribute to cluster efficiency. The goal was to optimize perforation design parameters and improve cluster efficiency for a given stage, and thus the well in its entirety. A two well trial was conducted across the same bench formation on a single pad in Midland Basin. In all, eight perforation designs were created using two set points (high and low) across three key perforation design variables: 1) perforation phasing & orientation, 2) perforation diameter, and 3) perforation friction. Each design was repeated eight times (i.e. eight stages) to allow for a meaningful number of data points. After stimulation operations were conducted an acoustic imaging technology was utilized to assess the perforation dimensions for all perforations post-fracture for all stages as well as various sets of pre-fracture perforations. In total, the trial was conducted across 64 stages (8 perforation designs × 8 stages per perforation design) using a Design of Experiments (DoE) method to assign low or high set points for each perforation design to best ascertain the impact of each test variable on the response variable as well as test for multicollinearity across the test variables. The uniformity index metric was used as a proxy for cluster efficiency and was calculated using two methods (a) eroded perforation area increase, and (b) post frac perforation area. Based upon the results obtained from the acoustic imaging data set and the subsequent data analysis, the uniformity index improved with a perforation design that had higher average perforation friction, smaller perforation hole shot size and a 0 degree in-line perforation orientation. The field trial results of uniformity index provided high quality statistical quantification of optimum perforation design parameters and its impact on cluster efficiency.
- Research Report > New Finding (0.68)
- Research Report > Experimental Study (0.54)
- Geophysics > Borehole Geophysics (0.69)
- Geophysics > Seismic Surveying > Borehole Seismic Surveying (0.55)
- North America > United States > Texas > Permian Basin > Midland Basin (0.99)
- North America > United States > Texas > Permian Basin > Delaware Basin (0.99)
- North America > United States > South Dakota > Williston Basin > Bakken Shale Formation (0.99)
- (4 more...)
Geophysical Software and Algorithms papers must describe a useful algorithm for solving a problem of geophysical significance. Papers should describe a problem, how the algorithm is meant to solve the problem, and the workings of the algorithm itself. Well documented ASCII source code must be included as part of the submission, along with sufficient supporting files to allow computer-literate readers to run and verify the code. The source code and supporting documentation do not need to be included in the text of the paper itself, but will be reviewed as an integral part of the submission. The algorithm must be the focus of the code.
- Information Technology > Software (1.00)
- Information Technology > Software Engineering (0.85)
- Information Technology > Communications > Collaboration (0.40)
SPE's peer review process provides invaluable constructive feedback from experts in your field, allowing you to make a good paper even better. How does the peer-review process work? Authors are encouraged to submit technical papers for publication in SPE Journal. We welcome both conference papers and papers submitted directly for review. After submitting your paper, SPE Journal's editors will identify technical reviewers who will evaluate your paper's criteria for publication and provide constructive feedback.
- Reservoir Description and Dynamics (1.00)
- Management > Professionalism, Training, and Education > Communities of practice (0.96)
- Data Science & Engineering Analytics > Information Management and Systems > Knowledge management (0.96)
- Data Science & Engineering Analytics > Information Management and Systems > Artificial intelligence (0.69)
The proliferation and increasing sophistication of AI-assisted language tools (such as ChatGPT) have opened new avenues for research, but the ethics and best practices for their use are still evolving. These tools may generate useful information and content but are also prone to errors and inconsistencies. AI language tools may not be listed as an author. Any AI-generated content that is used within a manuscript should be thoroughly vetted, fact checked, and disclosed. If AI language tools are used within a manuscript, their use should be clearly explained within the methodology or acknowledgement section of the paper. If AI-generated content is included within a manuscript without an explanation, this can be grounds for rejection of the work at the discretion of SPE and may result in a code of conduct review.
The Impact of Autonomous Inflow Control Valve on Improved Oil Recovery in a Thin-Oil-Rim Reservoir
Taghavi, Soheila (University of South-Eastern Norway / InflowControl AS (Corresponding author)) | Aakre, Haavard (InflowControl AS) | Tahami, Seyed Amin (University of South-Eastern Norway) | Moldestad, Britt M. E. (University of South-Eastern Norway)
Summary Oil production from thin-oil-rim fields can be challenging as such fields are prone to gas coning. Excessive gas production from these fields results in poor production and recovery. Hence, these resources require advanced recovery methods to improve the oil recovery. One of the recovery methods that is widely used today is advanced inflow control technology such as autonomous inflow control valve (AICV). AICV restricts the inflow of gas in the zones where breakthrough occurs and may consequently improve the recovery from thin-oil-rim fields. This paper presents a performance analysis of AICVs, passive inflow control devices (ICDs), and sand screens based on the results from experiments and simulations. Single- and multiphase-flow experiments are performed with light oil, gas, and water at typical Troll field reservoir conditions (RCs). The obtained data from the experiments are the differential pressure across the device vs. the volume flow rate for the different phases. The results from the experiments confirm the significantly better ability of the AICV to restrict the production of gas, especially at higher gas volume fractions (GVFs). Near-well oil production from a thin-oil-rim field considering sand screens, AICV, and ICD completion is modeled. In this study, the simulation model is developed using the CMG simulator/STARS module. Completion of the well with AICVs reduces the cumulative gas production by 22.5% and 26.7% compared with ICDs and sand screens, respectively. The results also show that AICVs increase the cumulative oil production by 48.7% compared with using ICDs and sand screens. The simulation results confirm that the well completed with AICVs produces at a beneficial gas/oil ratio (GOR) for a longer time compared with the cases with ICDs and sand screens. The novelty of this work is the multiphase experiments of a new AICV and the implementation of the data in the simulator. A workflow for the simulation of AICV/ICD is proposed. The simulated results, which are based on the proposed workflow, agree with the experimental AICV performance results. As it is demonstrated in this work, deploying AICV in the most challenging light oil reservoirs with high GOR can be beneficial with respect to increased production and recovery.
- Asia (1.00)
- North America > United States > Wyoming > Carbon County (0.65)
- Europe > Norway > North Sea > Northern North Sea (0.49)
- Research Report > New Finding (1.00)
- Research Report > Experimental Study (1.00)
- South America > Colombia > Putumayo Department > Putumayo Basin > Acordionero Field (0.99)
- Europe > Norway > North Sea > Northern North Sea > South Viking Graben > Vana Basin > RL 088 BS > Block 25/4 > Alvheim Field > Lista Formation > Våle Formation (0.99)
- Europe > Norway > North Sea > Northern North Sea > South Viking Graben > Vana Basin > RL 088 BS > Block 25/4 > Alvheim Field > Lista Formation > A2 North Heimdal T60 Formation (0.99)
- (36 more...)
- Well Completion > Completion Monitoring Systems/Intelligent Wells > Flow control equipment (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization (1.00)
- Reservoir Description and Dynamics > Improved and Enhanced Recovery (1.00)
- Production and Well Operations > Well & Reservoir Surveillance and Monitoring (1.00)
Hybrid Long Short-Term Memory and Convolutional Neural Network Architecture for Electric Submersible Pump Condition Prediction and Diagnosis
Liu, DongJiang (School of Petroleum Engineering, China University of Petroleum (East China) / Institute of Oil and Gas Extraction Engineering, Ministry of Education, China University of Petroleum (East China)) | Feng, Guoqiang (School of Petroleum Engineering, China University of Petroleum (East China) / Institute of Oil and Gas Extraction Engineering, Ministry of Education, China University of Petroleum (East China) / Shandong Oil Recovery Software Technology Research Center (Corresponding author)) | Feng, Guoyong (Huantai Oil Production Management Area, Dongsheng Company, Sinopec Shengli Oilfield Co.) | Xie, Lijie (School of Petroleum Engineering, China University of Petroleum (East China) / Institute of Oil and Gas Extraction Engineering, Ministry of Education, China University of Petroleum (East China))
Electric submersible pump (ESP) is one of the common artificial lift technologies in offshore production systems. ESP failures are the main cause of the decline in the production efficiency of oil wells. Early warning and diagnosis of ESP failures are crucial to improve well production efficiency. In this study, a hybrid model of long short-term memory neural network and convolutional neural network (LSTM-CNN) for accurate early warning and diagnosis of ESP faults is proposed, based on electrical data as the basis of analysis. Using hyper-parameters to optimize the LSTM neural network structure and highly fit the field electrical data so that it can be applied to anomaly prediction before ESP faults, the results show that the optimized LSTM model with R (test set) = 0.79, root mean square error (RMSE) (test set) = 0.89, which can predict the future electrical data more accurately, and the predicted data are plotted in the polar coordinate system to simulate the ammeter card as the validation set. The ammeter card data set is simulated by collecting electrical data from different working conditions, which is expanded using data expansion, and different CNN models are trained to fine-tune the parameters using transfer learning. The results show that the GoogLeNet model has a significant diagnostic accuracy of 97%, which is 2% and 18% better than VGG16 and ResNet34, respectively. The model evaluation shows that the GoogLeNet model has good recall, F1-Score, and confusion matrix. The trained GoogLeNet model was applied to the validation set, and the hybrid LSTM-GoogLeNet model was found to be well-suited for ESP warning and diagnosis.
- Europe (0.93)
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- Asia > Middle East > UAE > Abu Dhabi Emirate > Abu Dhabi (0.15)
- Research Report > New Finding (1.00)
- Research Report > Experimental Study (0.86)