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Research on Quantitative Inversion Characterization of High-Definition Electrical Imaging Logging in Oil-Based Mud Based on BPNN and MPGA-LM Algorithm
Gao, Jianshen (Xian Shiyou University) | Ma, Ya-Ni (Xian Shiyou University) | Jiang, Liming (China National Logging Corporation) | Lu, Chunli (China National Logging Corporation) | Shi, Juncheng (China National Logging Corporation)
Electrical imaging logging in OBM (oil-based mud) has been developed for some time and is gradually playing an important role in the description of deep carbonate and shale reservoirs. Quantitative characterization of reservoir rock parameters such as resistivity is one of the most innovative developments in this field. The development of this technology needs to address and resolve four core issues: a wide range of parameter variations, removal of mud-cake influence in low-resistivity formations, dielectric rollover in high-resistivity formations, and multi-frequency dielectric dispersion effects. To address the aforementioned issues, the joint use of a BPNN (Backpropagation neural network) and the MPGA (multiple population genetic algorithm)-LM (Levenberg-Marquardt) algorithm for high-resolution quantitative imaging is proposed. First, using the theory of physics model-driven approach, numerical simulation is utilized to calculate the well logging response data under the influence of multiple parameters, thereby establishing a forward response database. Then, within the forward response database, the instrument response function is fitted using BPNN, to compress the data volume. Next, based on the fitted response function, an inversion method for three parameters, including reservoir rock resistivity, permittivity, and plate standoff, is established using the LM algorithm optimized with MPGA. The results indicate that the use of a three-layer BPNN enables rapid and accurate calculation of the electrical imaging logging response in OBM. The calculation of a single point only requires 0.1 ms with an accuracy of over 99%. The MPGA-LM algorithm exhibits stronger stability and improved inversion accuracy, with a single point inversion time of only 2 ms, and contributes to the high-definition quantitative description of electrical imaging logging in OBM, which is important in characterizing formation structures, distinguishing formation fractures etc.
- Asia > China (0.93)
- Europe > Norway (0.67)
- North America > United States > Texas > Montgomery County (0.28)
- Geophysics > Borehole Geophysics (1.00)
- Geophysics > Seismic Surveying > Borehole Seismic Surveying (0.67)
- Asia > China > Shanxi > Ordos Basin (0.99)
- Asia > China > Shaanxi > Ordos Basin (0.99)
- Asia > China > Gansu > Ordos Basin (0.99)
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 authorsโ 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 > Neuquรฉn > 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)
Engineering a Synthetic Friction Reducer to Combat Undesirable Formation of FR-Metal Complex/Precipitation in Slickwater Fracturing
Sun, Hong (Solvay, The Woodlands, TX, USA) | Lin, Ying-ying (Solvay, The Woodlands, TX, USA) | Geng, Xi (Solvay, The Woodlands, TX, USA) | Wickramasinghe, Lanka (Solvay, The Woodlands, TX, USA) | Zalluhoglu, Fulya (Solvay, The Woodlands, TX, USA) | Wang, Qing (Solvay, The Woodlands, TX, USA)
Abstract During stimulation and production, a highly viscous and rubbery precipitation can form due to incompatibility of friction reducer polymers (cationic, anionic or amphoteric) with ferric ions, particularly in formations with high iron content. This material plugs up proppant packs, even production strings, and is extremely detrimental to well productivity. A straightforward sequestration approach with chelants does not work because of poor outcome and prohibitive economics. Compatible biopolymer FRs, as an alternative approach, have limited applications due to their moderate FR performance compared to synthetic PAM based polymers. This work shows the development of a novel synthetic friction reducer to address this challenge. The polymer was designed by systematically optimizing monomer compositions, molecular weight and surfactant packages. Friction reduction performance of the newly developed FR was evaluated in friction loops under various water conditions. Iron tolerance tests were performed by mixing ferric iron with prehydrated FRs under different pHs, at high concentrations, and salinities. The mixture solutions were then placed in a water bath for heat treatment to simulate downhole conditions and to accelerate the formation of the ferric/FR complexes. Comparative experiments were performed using conventional FRs. In order to probe the interaction between polymers and the iron species, zeta potential analyzer was applied to measure charge changes of the polymer strands. The newly developed FR showed superior FR performance with fast hydration and high overall friction reduction, in both fresh water and synthetic brines. In iron tolerance tests, rubbery precipitations formed in solutions for all three types of conventional FRs, while no such precipitations were observed with the newly developed FR, even in the presence of 500 ppm ferric ion. This test was repeated in a wide range of pH and salinity conditions and no significant viscosity change of the FR polymer solution was observed before and after the test. Zeta potential measurements confirmed the validity of the polymer design to minimize the interaction between the new FR polymer and iron ions. This paper demonstrates that the newly developed friction reducer successfully solves the incompatibility issue of FRs with iron spices, i.e., without flocculation on the surface or formation of gummy precipitations downhole. Its superior friction reduction performance with no concerns of potential damages make it a strong candidate for iron-rich fields. Mechanism of the interaction between iron and synthetic polymers is proposed and confirmed by zeta potential results. The manuscript discusses in depth the strategy of the design of the newly developed copolymer, including selection of monomers, molecular weight control, and inverting surfactants.
- North America > United States > Texas (0.69)
- North America > United States > Oklahoma (0.47)
- North America > Canada > Alberta > Stettler County No. 6 (0.24)
- (3 more...)
- Energy > Oil & Gas > Upstream (1.00)
- Water & Waste Management > Water Management > Lifecycle > Treatment (0.35)
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (0.35)
Abstract Driven by increased production rewards, multiple operators in the United States have been improving their unconventional wells by increasing the lateral length. Several "superlaterals" with lengths above 23,000 ft (7 km) have been drilled successfully in several U.S. basins. This paper describes the technical challenges to drill and run casing in superlaterals and the difficulties to make them possible in the Vaca Muerta unconventional play. Several mechanical and hydrodynamics models within the geomechanics constraints are combined with real-time data to illustrate the limitations observed in shorter wells and the steps needed to successfully deliver superlaterals. Drilling and running casing successful operational practices as well as "superlateral related" failures are also discussed. As the lateral length increases, torsional and tensional loads increase. Buckling also becomes a much larger problem to overcome. Geomechanical constraints are a major challenge, especially at higher mud weights. The stability margin becomes narrower when transitioning from a shorter lateral to a superlateral because hydraulic friction increases with the lateral length and the risk of losses is increased. Furthermore, wellbore stability is paramount to keep drag in acceptable values for a successful casing run. Conventional drill strings and casing configurations may not reach bottom and design changes are likely to be required. Better attention to the drilling and casing running practices is key to prevent catastrophic events. In Vaca Muerta, the geomechanical constraints are particularly important. Changes in the wellbore geometry and/or drill pipe size can be required to maintain an acceptable mud weight window. When Quintuco and Vaca Muerta are drilled in the same section, the use of Managed Pressure Drilling (MPD) has reduced the effect of the uncertainties on the pore pressure and allowed successful drilling of shorter laterals, but as the lateral length increases, MPD alone is insufficient to mitigate this risk.
- North America > United States > Pennsylvania (0.93)
- South America > Argentina > Neuquรฉn Province > Neuquรฉn (0.28)
- North America > United States > West Virginia > Appalachian Basin > Utica Shale Formation (0.99)
- 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)
- (24 more...)
Abstract Fortin de Piedra is an important unconventional field in Argentina's Neuquรฉn basin with over 100 horizontal gas producer wells in the lower Vaca Muerta formation. Extensive multi-stage hydraulic fracturing operations provided a spatial mapping of operational variables such as pre- and post-fracturing instantaneous shut-in pressures, or ISIP. Such ISIP magnitude maps revealed spatial patterns that correlated with the presence of structural faults interpreted from seismic data. Because of the relationship between ISIP and relevant geomechanical variables (and associated phenomena) involved in hydraulic fracturing operations, a detailed geomechanical model was constructed and employed in an attempt to explain such variations in ISIP magnitudes. The target lower section of Vaca Muerta shale formation shows a high lateral depositional continuity in the Fortรญn de Piedra field, allowing seismic inversion products to be used as an input for the population of the geomechanical model. Still, structural faults crossing the Vaca Muerta formation were the primary hypothesis for the source of local variation of the stress field, associated to the stress relaxation caused by rock matrix degradation in the region nearby interpreted faults planes. The model made use effective medium theory for mechanical property degradation in the vicinities of the faults that crossed Vaca Muerta formation. The mechanical properties of the near fault-elements were set to match the local trend of variation in the minimum total horizontal stress that was seen in nearby ISIPs. The ISIPs mapping signatures were captured in many of the analyzed faults. They appeared to show a horizontal stress relaxation region near the central part of the fault and a stress concentration region near the tip. With this model, we could integrate quantitatively ISIPs measurements and drilling events that would have remained unexplained with a model without faults. This novel approach allows us the systematic usage of spatially distributed by-products of hydraulic stimulation operations, to be incorporated in the process of building a geomechanical model for future planning and prognosis of undeveloped sequences of the Vaca Muerta formation within the Fortรญn de Piedra field.
- South America > Argentina > Neuquรฉn Province > Neuquรฉn (1.00)
- North America > United States > California > San Francisco County > San Francisco (0.29)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Petroleum Play Type > Unconventional Play > Shale Play (0.89)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (0.57)
- South America > Argentina > Patagonia > Neuquรฉn > Neuquen Basin > Vaca Muerta Shale Formation (0.99)
- South America > Argentina > Neuquen > Neuquen Basin > Fortin De Piedra Field (0.99)
- Oceania > Australia > South Australia > Cooper Basin (0.99)
- (8 more...)
Use of Advanced Simulation Software to Understand Drilling Challenges that Leads to the Selection of PDC Drill Bit, Reduced the Risk of Failure and Improves Performance by 22% at South Argentina
Hernandez, Jesus (La Universidad del Zulia / Baker Hughes) | Delorenzi, Rodrigo (Baker Hughes) | Gonzalez, Andres Pedro (Baker Hughes)
Abstract The objective of this paper is to demonstrate a comprehensive methodology for an efficient selection process of a Polycrystalline Diamond Compact (PDC) drill bit design tailored to a given drilling conditions with the use of digitalization. This is achieved by utilizing a software that recreates the PDC design with a polygonal mesh model. Then it's subjected to dynamic drilling conditions; which include the application of loads equivalent to Weight on Bit (WOB), and a rotational motion, equivalent to Revolution Per Minute; of solids that have mechanical properties calibrated with data from pressurized drilling tests in specific rock types. After the incorporation of data from offset wells and the target well, the software is capable to simulate the loads and stress that the PDC will be subjected to when drilling the specific environment. This will allow to analyze the bits performance and durability, thus predicting the challenges, to verify if the drill bit design itself will comply with the application's requirements. After completing an iterative simulation process, where the geometries and positioning of features of the PDC drill bit are modified until a desired response is completed; a final design is obtained that can be tested in a real life well. The implications of this approach are promising to enhance efficiencies that can ultimately reduce time and cost for operators, fostering more efficient drilling practices for the industry. Introduction As the demand for energy resources continues to surge and the need for safer and more sustainable drilling operations intensifies; like in the past decade, where the Oil and Gas Industry has been using unconventional ways to extract hydrocarbons, so does the need to operate with tools and practices that can be more reliable, and adaptive to the specific challenges that this brings. Since decades ago, where the use of several number of roller cone bits to drill a section at a low rate of penetration, evolved to PDC Designs, that can drill the same interval in one run, at an increased rate of penetration. The optimization of drill bits stands as a corner stone within the oil and gas industry, deeply shaping the efficiency, productivity, and cost-effectiveness of field operations. This process and its technological advancements have consistently influenced drilling practices.
- Geology > Geological Subdiscipline (0.48)
- Geology > Rock Type (0.34)
- South America > Argentina > Patagonia > Golfo San Jorge Basin (0.99)
- South America > Argentina > Chubut > Golfo San Jorge Basin > El Tordillo Field (0.99)
Abstract In the Vaca Muerta wells, operators face daily difficulties due to casing issues. The industry presently lacks efficient early-stage detection approaches for addressing these problems, which often results in decision-making only after the event has occurred. This situation leads to further operational complications and adverse economic consequences. In our research, we present a novel tool designed to detect anomalies, which will enable us to establish a contingency plan for effective response. Unusual casing collar locator (CCL) readings sometimes indicate where the wireline gets stuck in later runs. Although not specifically designed for detecting casing issues, irregular CCL fluctuations might hint at problems with casing diameters. Initially, we applied an isolation forest-based anomaly detection algorithm to identify CCL disturbances, but not in real-time. In a recent pad, pump-down runs could not be executed due to casing restrictions. This incident led us to shift the frac fleet and use a multi-finger caliper tool. The results allowed us to tunned the anomaly detector tool (ADT). Blind tests on historical stages showed our ADT successfully identified problematic stages from casing restrictions. The research seeks to use this tool as a first step to make informed decisions on contingency plans to mitigate related problems to this. Introduction Casing deformation has been observed in conventional and unconventional reservoirs, at the recent years has gained more attention in shale developments, several cases has been reported in Canada, China and Argentina. It is recommended to review two technical publications to have a better understanding about the possible causes of casing deformation generation. The first one, Casero and Rylance (2020) presented an initial approach about casing deformation that can be influenced by: a- well construction (tubular, cement), b-subsurface (tectonics and rock properties) and c-operations; and several case histories around the world. The second one, Russel (2021) shown different diagnostic tool to collect information about deformation; mechanisms and root causes in unconventional well focusing on cases with slip on natural fractures and bedding planes.
- North America > United States (1.00)
- South America > Argentina > Neuquรฉn Province > Neuquรฉn (0.47)
- South America > Argentina > Patagonia > Neuquรฉn > Neuquen Basin > Vaca Muerta Shale Formation (0.99)
- South America > Argentina > Patagonia > Neuquรฉn > Neuquen Basin > Loma Campana Field > Vaca Muerta Shale Formation (0.99)
- South America > Argentina > Patagonia > Neuquรฉn > Neuquen Basin > Loma Campana Field > Lower Agrio Formation (0.99)
- (4 more...)
The Application of a New Variable Pressure Decline-Curve Analysis Technique to Unconventional Reservoirs in Argentina
Maraggi, Leopoldo M. Ruiz (The University of Texas at Austin) | Tuero, Fernando (VYP Consulting Services) | Walsh, Mark P. (The University of Texas at Austin) | Lake, Larry W. (The University of Texas at Austin)
Abstract Traditional rate-transient analysis (RTA) is used to match the past and forecast the future production history of unconventional wells. This approach has several drawbacks: (a) the analysis of a single well is time-consuming, (b) it uses two approximate transformations: rate normalization and material balance time, and (c) the interpretation is subjective. Recently, we have developed a new variable pressure decline-curve analysis (DCA) method. This new approach delivers fast and accurate history matches and forecasts, removing the need for subjective interpretation and avoiding potential errors caused by rate normalization and material balance time transformations. The goal of this paper is to apply of this new variable pressure DCA method to unconventional reservoirs in Argentina. The new variable pressure DCA technique performs sequential optimizations. In each iteration, the algorithm sequentially estimates: (1) the reservoir model parameters, (2) the pressure change, and (3) the initial reservoir pressure. The outputs of the method are the following: (a) the model's parameters, (b) the production history-match, and (c) estimates of the bottomhole flowing pressure (BHP) and initial reservoir pressure. In addition, the technique allows the user to select any decline-curve model, numerical, analytical, or empirical model. We illustrate the application of the technique for a tight-oil and a shale gas well using three different models: the constant-pressure solution of the diffusivity equation, the logistic growth model, and the Arps hyperbolic relation. The analysis of production from unconventional wells shows that the new technique provides excellent production history-matches using different reservoir models. We show that the estimated BHP using our technique is in good agreement with the calculated BHP for the wells under study. Furthermore, the technique is computationally fast; it only requires around 20 seconds to analyze and history-match the production of a well. For the tight-oil well, we perform a hindcast analysis using only the flowback data to match the model parameters which were then used to forecast the production history with excellent agreement. The method provides the possibility to history-match and estimate the future behavior of wells under different choke management scenarios. This work illustrates the application of a recently developed variable pressure DCA technique that efficiently performs automated production history-matches and forecasts of unconventional reservoirs. The technique provides improved estimates of the BHP and initial reservoir pressures. It can be used with any decline model. In addition, the method is computationally inexpensive and does not require the use of diagnostic plots and the interpretation of a practitioner. The major contributions of the present method are its flexibility to incorporate any decline-curve model and its speed to analyze and history-match the production of unconventional wells. Finally, we developed a web-based application to provide readers with a hands-on experience of this new technique.
- North America > United States > Texas (1.00)
- South America > Argentina (0.70)
- North America > Canada (0.69)
Integration of RCA and SCAL with Image Logs Leads to a Unique High Resolution Technique to Evaluate Laminated Clastic Reservoirs of Black Sea, Turkey
Isdiken, Batur (Tรผrkiye Petrolleri Offshore Technology Center TP-OTC) | Dutta, Tanmoy (Tรผrkiye Petrolleri Offshore Technology Center TP-OTC) | Yรผce, Ugur (Tรผrkiye Petrolleri) | Kiliรง, Mert (Tรผrkiye Petrolleri Offshore Technology Center TP-OTC)
Abstract Deep water gas reservoirs in the Western Black Sea consist of highly laminated heterogeneous and complex sand/shale sequences. A petrophysical volumetric model was created by combining the triaxial induction resistivity data with the Thomas-Stieber (1975) sand-shale volumetric model to better evaluate low-resistivity pay zones in highly laminated shaly sand sequences. Although the results from this method are volumetrically almost correct, they are quite insufficient to deal with the distinctions between finely laminated sand, silt and shale. In order to calculate volumetric petrophysical parameters, such as porosity and water saturation, which are linearly or non-linearly derived from the sand/shale fraction of the rock volume, accurate measurement of laminar shale volume in shaly sand sequences is an essential first step. Even though GIIP does not change much, the volumetric method presents a particular challenge in terms of continuity of gas bearing layers when there is water located in both above and below the gas-bearing sands. High-resolution wireline image tools with a vertical resolution of 0.5 cm can capture bed thicknesses and boundaries of these sand layers, enabling the determination of the net to gross sand ratio. However, imaging technologies by themselves are unable to determine precise porosity and water saturation. By statistically evaluating extensive volumes of core data (RCA and SCAL) and image logs, a new high-resolution methodology offers a simple and innovative method to compute porosity and saturation. A partially cored reservoir section example is used to demonstrate the entire technique. This approach does not require standard log deconvolution. The uncertainty has been understood after comparing the results between the volumetric model and high-resolution model. By using the methods described in this paper, it is possible to position the perforation interval more precisely and reduce uncertainty for volumetric petrophysical calculations in complex highly laminated clastic reservoirs. The results show that low resistive laminated clastic reservoirs can be extremely productive, showing reservoir quality comparable to that of productive thick sands.
- North America > United States (1.00)
- Europe (1.00)
- Asia > Middle East > Turkey (0.50)
- Research Report > New Finding (0.48)
- Overview > Innovation (0.48)
- Research Report > Experimental Study (0.34)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Sandstone (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (1.00)
- Well Drilling > Drilling Operations > Coring, fishing (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Exploration, development, structural geology (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Open hole/cased hole log analysis (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Core analysis (1.00)
While downhole pumps and sucker rods are the chief components of a sucker-rod lift type artificial lift system, a number of other components are also used in the subsurface portion of the system. These include tubing, tubing anchor-catchers, tubing rotators, sinker bars, rod centralizers, and paraffin scrapers. Tubing provides detailed information on the design, selection, and use of tubing for production wells. As related to most sucker-rod-lifted wells, the standard weight of external-upset-end, API tubing[1] should be used because of the increased wall thickness in the threaded ends. Thus, if there is rod coupling-on-tubing wear, more life and fewer leaks will be realized than if nonupset API tubing is used. Using API Grade J55 tubing, consider full-body normalizing after upsetting to prevent "ringworm corrosion" in the heat-affected upset region when the tubing is placed in corrosive (H2S or CO2) service.
- 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)
- (21 more...)
- Information Technology > Knowledge Management (0.40)
- Information Technology > Communications > Collaboration (0.40)