Layer | Fill | Outline |
---|
Map layers
Theme | Visible | Selectable | Appearance | Zoom Range (now: 0) |
---|
Fill | Stroke |
---|---|
Collaborating Authors
YPF
An Innovative Methodology to Measure Total and Effective Porosity on Rock Samples of Source Rock. Case Study: Vaca Muerta Formation
Domené, Esteban (YPF Tecnología SA) | Masiero, Diana (YPF Tecnología SA) | Juarez, Jorge (YPF Tecnología SA / CONICET) | Monti, Mariana (YPF Tecnología SA) | Cipollone, Mariano (YPF Tecnología SA) | López, Lourdes Vera (YPF) | Bernhardt, Carolina (YPF)
Abstract Laboratory rock characterization is fundamental in helping understand the subsurface, its components and thereafter infer where and how to proceed with the extraction of hydrocarbons. Well logging tools are equally important and should be considered complementary to laboratory results. In this work we propose an integrated and innovative laboratory methodology focused on non-destructive characterization and minimizing the amount of sample required. The full methodology includes petrophysical, mineralogical and geochemical characterization. Results on total and effective porosity will be presented, compared and validated with well logs from three different wells in oil window, corresponding to the Vaca Muerta formation. Introduction The oil and gas industry relies on petrophysical studies to make important economic decisions and guide the extraction process. This information can be obtained in situ using well logging tools (Coates 1999), or in the lab by extracting rock samples (cores, rotary sidewall plugs, outcrops, or cuttings). Complete characterization of conventional reservoirs is somewhat a standard practice and there is even a recommended practice for core analysis (API RP 40). On the other hand, unconventional plays, in particular shale rocks with heterogenous lithologies and presence of organic matter still represent a challenge. Thus, there is a requirement in the industry to develop innovative characterization workflows. Laboratory analysis requires the extraction of rock samples from the subsurface, which is a very time consuming and expensive process. The value of rock samples favors the development of characterization techniques that are non-destructive and require less amount of rock (Masiero 2022). With this in mind, we present petrophysical results obtained on rock samples from three different wells from the Vaca Muerta Formation. This formation is a marine source rock with the following characteristics: average TOC content 1-8%; moderate depths of 3150 m; overpressure between 47-61 MPa; no expandable clays in mature areas; and different landing zones for oil, wet and dry gas production (Brisson 2020, Dominguez 2019, Sagasti 2014, Spacapan 2021, Uliana 1993,). The focus is set on correctly measuring total and effective porosity, using the least amount of sample possible and with non-destructive experiments. Porosity is one of the most important rock properties, allowing for the estimation of hydrocarbon reserves and thus value a formation, basin or well.
- South America > Argentina > Patagonia Region (1.00)
- South America > Argentina > Neuquén Province > Neuquén (1.00)
- Geology > Geological Subdiscipline > Geochemistry (1.00)
- Geology > Geological Subdiscipline > Economic Geology > Petroleum Geology (0.72)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (0.55)
- South America > Argentina > Patagonia > Neuquén > Neuquen Basin > Vaca Muerta Shale Formation (0.99)
- North America > United States > California > Sacramento Basin > 2 Formation (0.99)
- South America > Argentina > Patagonia > Neuquén > Neuquen Basin > Vaca Muerta Field > Vaca Muerta Shale Formation (0.98)
Abstract The topic of this paper is related to the study of what is known in the industry as the "parent-child" effect. This is accomplished by using a coupled hydraulic fracture and reservoir simulator to perform a sensitivity analysis of the impact on the results of the EUR of the child well, based on a conceptual static model for the hub core of the Vaca Muerta, considering two landing zones, different spacing between wells, degree of depletion of the parent well, the addition of a second child well and the use of an improved completion design for the child well. The objective is to investigate, through sensitivity analysis, the scenarios with the greatest impact on the EUR of the child well and to measure the magnitude or influence of each of them. Once the dynamic simulation model is calibrated, the first step is to locate and stimulate a fictitious child well in the vicinity of its parent well and perform various sensitivity analyses by varying one variable while holding the other variables constant. We considered two key variables: the well spacing (200m, 300m, 400m and 600m) and the time lag between the start of production of the child well and its parent well, with depletion intervals ranging from 0 to 5 years. A second sensitivity analysis is performed by adding two child wells, 300m and 600m from the parent well, to be stimulated simultaneously using the previous time intervals. Finally, using the 300m well spacing scenario, an improved completion design for the child well was proposed and compared to the actual completion. The result of analyzing a single child well and varying the well spacing over time intervals was, as expected, the improvement for the impairment of the child well EUR at greater distances from the depletion area, with no effect observed for the 600m spacing situation. For the case of two child wells analysis, the EUR for the outer child well at 600m showed some degree of effect (different from the previous 600m case) and for the inner child well at 300m the EUR response was similar to the single child well at 300m spacing. Finally, changing the completion design drivers (specifically volumes per cluster) of the child well showed an improvement in child well EUR reduction over the current design. The significance of this project is to establish a workflow, or methodology, for evaluating the influence of the parent-child effect on EUR using numerical simulations that can be applied and adapted to any unconventional formation characteristics and input variables (well spacing, completion design, etc.), allowing an informed strategy definition for field development and optimized EUR. This working methodology is based on a fracture simulation software that integrates 3D reservoir model, hydraulic fracturing, and production simulations, using a single package designed to analyze the entire life cycle of a well, from fracturing to long-term production, making it suitable for the objectives of this project.
Abstract This methodology was evaluated in wells with natural flow and Gas Lift (GL) in Non-Conventional oil in Vaca Muerta and its use as a paraffin cleaning tool was technically validated through analyses carried out with the multidisciplinary team. Also, the What if risk analysis with which improvement actions were recommended based on the safety of people, the environment, and the company. In the analysis of previous interventions, it was detected that some SL interventions had more time, or it was not possible to dewax the well with the use of conventional methodologies. Therefore, in order to avoid the use of higher cost equipment (Coiled Tubing), we evaluated and implemented the use of a hot tool in wells with total tubing obstruction due to paraffin. The main objective is to dewax the wells in less time and cost by using a hot tool and compare it with conventional methodologies used in interventions with Slick line equipment. Additionally, to reduce production loss and improve efficiency in the use of resources. To achieve this, we took on the following challenges: ✓ Validate the functionality of the service and the efficiency of the equipment for paraffin cleaning in the well. ✓ To elaborate and validate the operational program and the necessary documentation for the intervention based on the safety of people, the environment, and the company. ✓ Evaluate the efficiency of the operation in terms of time and cost reduction. As a result, the safety of people, the environment and the company were guaranteed throughout the intervention and the functionality of the dewaxing equipment service and operational documents of the intervention were validated. Additionally, the use of the hot tool was rationalized, obtaining profitable results due to a saving of 73% compared to a Coiled Tubing intervention and a savings of 21% compared to a conventional intervention. Also, it is important to say that the three pilot's wells were dewaxed totally.
- South America > Argentina > Patagonia > Neuquén > Neuquen Basin > Vaca Muerta Field > Vaca Muerta Shale Formation (0.98)
- South America > Argentina > Patagonia > Neuquén > Neuquen Basin > Loma Campana Field > Vaca Muerta Shale Formation (0.89)
- South America > Argentina > Patagonia > Neuquén > Neuquen Basin > Loma Campana Field > Lower Agrio Formation (0.89)
- (2 more...)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs (1.00)
- Production and Well Operations (1.00)
- Well Completion > Completion Installation and Operations > Coiled tubing operations (0.72)
- Facilities Design, Construction and Operation > Flow Assurance > Precipitates (paraffin, asphaltenes, etc.) (0.47)
From Cutting to Sidewall Core, a Way to Achieve a Deeper Understanding Based on Clustering and Workflow Strategies. Case Study: Palermo Aike Formation, Austral Basin
Cipollone, Mariano (Y-TEC / UNAJ) | Bedini, Paula (Y-TEC) | Brea, Fabian (Y-TEC) | Tortora, Leonardo (Y-TEC) | Alejandra, Diana María (Y-TEC) | Pelegrí, Ezequiel Gonzalez (Y-TEC) | Fischer, Alejandra (Y-TEC) | Iturreria, Santiago Genta (Y-TEC) | Domené, Esteban (Y-TEC) | Pascariello, Maria Eugenia (YPF)
Abstract The objective of this work is to submit an innovative workflow where, we combine clustering techniques based on direct measurements over cutting with multidisciplinary studies performed in cutting and sidewall cores (SWC). The case studied corresponds SWC and cutting samples of 2 wells of the Palermo Aike Formation (PA), Tierra del Fuego, Austral Basin. In the first part, the results of the combined use of different compositional characterization tools on samples of drilling cuttings from wells that cross the Palermo Aike Formation in Tierra del Fuego are shown. We apply clustering techniques on direct measurements of XRF, colorimetry, well curves and total organic carbon allow obtain different groups (colors) which represent zones with compositional characteristics that define and individualize them. In each of these groups, more detailed petrographic, geochemical and compositional analyzes were carried out, which in principle allowed us to confirm the consistency with the direct measurements. This consistency allows the expansion of the detailed characterization to the entire range represented by the group. Then, through an integration of data from the set of wells studied, it was possible to identify different areas of interest with their own characteristics and these areas were correlated between the wells studied. In this step, we need to move forward to have a deeper understanding of the characteristics of the source rock. To reach this goal we apply a detailed and exhaustive workflow on sidewall cores (SWC) belonging to the areas of interest. The aim of the workflow is understanding the relationship between compositional, geochemical, petrographic and petrophysical characteristics. It means link the smaller-scale characterizations with the results obtained from the laboratory petrophysical measurements carried out on the samples. The synergy resulting from the different studies allowed us to understand the characteristics and behaviors of the groups. These deeper understanding was expanded to the groups described by cutting, connecting through characteristics the behaviors of zones without samples. Thus, it enabled us to define regions of interest and also, a deeper understanding of the mentioned areas.
- South America > Argentina > Tierra del Fuego Province (1.00)
- South America > Argentina > Neuquén Province > Neuquén (0.28)
- Geology > Geological Subdiscipline > Geochemistry (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock (0.74)
- Energy > Oil & Gas > Upstream (1.00)
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (0.46)
Abstract This paper objective is to present a case study to define an empirical correlation of oil performance with horizontal well's drilling and completion parameters in Field ‘L’ in Vaca Muerta, using simplified data analytics. This paper shall outline the methodology which include systematic approach of production data screening and selection, well performance parameter relation with drilling and completion design parameters discussion. Methods/Procedures The usage of empirical ’K coefficient’ in this data analytics to describe completion design efficiency was firstly introduced by Kuuskraa and Murray in 2021, who applied it on Mowry Shale wells in Powder River Basin, Wyoming. However, on top of replicating similar method to long term estimated oil recovery (EUR), this paper shall extend the ’K coefficient’ correlation concept to early time well performance that is often overlooked during production ramping up period which is crucial for optimum drawdown management practices. Results/Conclusions This methodology is applied to a shale oil in Field ‘L,’ Vaca Muerta formation in Argentina of more than 6 years of production data and more than 100 wells drilled. The result is used in estimating the performance of a new completion design, in cost effective and time efficient manner. Furthermore, it is also used as a tool in diagnosing current wells production performance problems and assessing optimum choke selection for variation of completion designs.
- South America > Argentina > Neuquén Province > Neuquén (1.00)
- South America > Argentina > Patagonia Region (0.85)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (0.93)
- Geology > Petroleum Play Type > Unconventional Play > Shale Play (0.65)
- South America > Argentina > Patagonia > Neuquén > Neuquen Basin > Vaca Muerta Shale Formation (0.99)
- South America > Argentina > Patagonia > Neuquén > Neuquen Basin > Vaca Muerta Field > Vaca Muerta Shale Formation (0.99)
- North America > United States > Wyoming > Powder River Basin (0.99)
- North America > United States > Montana > Powder River Basin (0.99)
Comparative Studies by Rock Eval Pyrolysis and its Impact on the Evaluation of Producible Fluids: Pozo Anticlinal Aguada Bandera Formation, Argentina
Iturrería, Santiago Genta (YPF Tecnologia) | Brea, Fabián (YPF Tecnologia) | Otegui, Gastón (YPF Tecnologia) | Guanco, Raúl (YPF Tecnologia) | Palafox, Gastón Iovine (YPF) | Brisson, Ignacio (YPF)
Abstract Rock-Eval pyrolysis is widely used as a screening technique, allowing for the characterization of source rocks in terms of potential, maturity, quality, and hydrocarbon content. In most cases, the method used with this equipment is the Basic/Bulk-Rock method. Originally developed to characterize source rocks in conventional reservoirs, its application in unconventional reservoirs (hybrids or shale plays) to evaluate the content of free hydrocarbons (HC) presents certain limitations and disadvantages. That is why IFP Energies Nouvelles developed a new method (Rock Eval Shale Play Method) for better estimation of free and/or absorbed hydrocarbons in unconventional reservoirs. In this work, we present a comparative study applied to lacustrine shale in the Golfo San Jorge Basin, Argentina, to assess how is the recovery of free and adsorbed hydrocarbons. The Rock Eval Shale Play method proved to be the most appropriate and the results obtained could be confirmed with high quality oil recovered in the well test. The characteristics of the recovered petroleum, combined with the results obtained in this study, lead to a favorable prospective outlook for the Pozo Anticlinal Aguada Bandera Formation as a potential Neocomian shale to continue evaluating. Introduction Rock-Eval pyrolysis is one of the analytical techniques used in petroleum geochemistry as a screening tool used to perform a quick evaluation of the source rock. This method is widely used by geochemists to obtain information regarding organic richness, source rock quality and thermal maturity. Basically Rock-Eval pyrolysis (developed and patented by IFP) is an open-system programmed pyrolysis method that subjects rock samples to a controlled heating and pyrolytic decomposition process, simulating the geological conditions that buried sediments experience over geologic time. The primary goal of this technique is to determine the organic richness, quality, and maturation state of sedimentary rocks, allowing geologists to assess their potential as source rocks for hydrocarbon (HC) generation. The method's fundamental principle lies in the pyrolysis of organic matter within rock samples, releasing various hydrocarbon compounds as well as CO2 and CO. By measuring the products of this thermal decomposition and cracking, geochemists can evaluate the potential of the source rock as an initial screening step.
- South America > Argentina > Patagonia (0.88)
- South America > Argentina > Neuquén Province > Neuquén (0.28)
- Geology > Geological Subdiscipline > Geochemistry (1.00)
- Geology > Geological Subdiscipline > Economic Geology > Petroleum Geology (1.00)
- Geology > Structural Geology > Tectonics > Compressional Tectonics > Fold and Thrust Belt (0.61)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (0.47)
- South America > Argentina > Patagonia > Neuquén > Neuquen Basin > Vaca Muerta Shale Formation (0.99)
- South America > Argentina > Patagonia > Golfo San Jorge Basin (0.99)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Shale gas (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Exploration, development, structural geology (1.00)
- Reservoir Description and Dynamics > Fluid Characterization > Geochemical characterization (1.00)
Abstract Friction reducers (FR) are typically polyacrylamides used in high-rate slickwater fracturing operations to reduce friction created during pumping operations. A key requirement for FR is that they need to disperse and hydrate in water quickly without creating fisheyes. The primary goal is to reduce pipe friction. When FR first came to the market, they were liquid and were pumped via the liquid additive systems on legacy equipment. Liquid FR had many challenges, though, as they involved a large onsite storage footprint, would freeze in cold weather operations, and could separate. As dry FR became the preferred chemical state for the product, it was found that legacy equipment was not ideal for pumping the product. Legacy solutions that were first used to hydrate the powdered form often required human intervention, which introduced service quality concerns and had environmental and health risks due to dusting. A new delivery mechanism was required to fit the needs of the product. A method has been developed to efficiently inject dry FR or high-viscosity FR (HVFR) during stimulation. In the new method, FR or HVFR in powder form are hydrated and injected directly into the suction of a blender or directly to the low-pressure side of the manifold trailer. The ability to discharge hydrated fluid at blender pressure enables the method to support standard or split-stream operations. This process is done on a skid, which substantially reduces the operational footprint at the wellsite compared to the conventional method; improves the rig-up procedure; and mitigates the health, safety, and environmental risks of the stimulation operation. The sensors and the control system of this unmanned unit enable the operator to optimize the injection rate of the dry FR or HVFR during the operation with a smart and digital approach for instantaneous changes in concentration. The designed solution is modular and versatile to address a wide range of FR and HVFR concentrations. One unit is capable of injecting dry FR at rate of 50 lbm/min, and the rate can be increased to 150 lbm/min by running three skids in parallel. This modular approach enables a fit-for-product delivery system that can address slickwater, hybrid, or high-concentration HVFR jobs. The fit-for-product HVFR delivery skid was first deployed outside of North America Land in Argentina in April 2023 and has become the preferred method for delivering dry FR and dry HVFR being used continuously in operations. As a result of this deployment, the team in Argentina has been able to manage large amounts of dry FR product with smaller footprint, less waste, and lower CO2 emissions. The percentage of hydraulic fracturing jobs with FR has been increasing in recent years outside of North America. As a subset of those jobs, there has also been an increase in jobs utilizing dry HVFR. Utilizing a powdered form of FR or HVFR has many benefits for both the operator and the service company but has also introduced operational challenges that are addressed by the modular approach, as performed in this study. The unit developed has the flexibility to work in conjunction with a wide range of fracturing blender designs to meet operator and service company operational needs. A case study provides an application example of the unit and the approach taken to improve the method for injecting dry FR and dry HVFR to optimize completion strategy on wellsite including a digital application.
- North America > United States (0.69)
- South America > Argentina (0.55)
Sustainable Distributed Polymer Injection Achieves 23% of Manantiales Behr Oil Production in 2 Years; Reusable Mobile Development that Reduces Polymer Back-Production
Juri, J. E. (YPF) | Dupuis, Guillaume (SNF) | Pedersen, Guillermo (YPF) | Ruiz, Ana (YPF) | Serrano, Viviana (YPF) | Guillen, Paula (YPF) | Ylitch, Ivana (YPF) | Ojeda, Natalia (YPF) | Gandi, Silvana (YPF) | Martino, Luis (YPF) | Lucero, Ariel (YPF) | Perez, Diego (YPF) | Vocaturo, Griselda (YPF) | Rojas, Ariel (YPF) | Viñales, Alejo (YPF) | Rivas, Christophe (SNF) | Massaferro, José Luis (YPF)
Abstract Implementing a polymer flooding plan from laboratory studies to expansion and optimization takes around 8 to 12 years. This work reports on an approach that increases the project's return on investment and reduce risks faced by Enhanced Oil Recovery (EOR) operations, especially considering the impact of timing in the current energy transition context. The oil demand is under rapid replacement because the energy transition is being accelerated by new policies (Cozzi et al 2022). Traditional linear economic models used in field development concepts often neglect important factors such as reusing facilities, water usage, chemical consumption related to water treatment, and sustainability aspects like integrating geothermal energy from produced water. As a result, these approaches contribute to environmental degradation, resource-supply price volatility, and implementation risks (Cozzi et al 2022). Our major contribution is the implementation of distributed polymer injection localised in reduced areas rather than a centralized infrastructure to massively inject polymer at a full-field scale. The distributed polymer injection with modular mobile polymer injection units (PIUs) targets the richest zones/sweet spots of bypassed oil. In this case, the logistics, and the construction of small modular mobile polymer injection units along with a cluster of ten injectors and nineteen to twenty-five producers ensure that the development cost will be below $5/bbl. The distributed polymer injection not only is efficient in kg of polymer per incremental barrel (on the injection side) but also rationalizes the total OPEX which includes the overall impact of polymer injection (water treatment and back-produced polymer treatment). Progressing this scenario is simple and depends mainly on the engineering and construction to move and mount rapidly the PIU from one sweet-spots to the next one. The development concept emphasizes speed over scale, aiming to minimize water usage, infrastructure footprint, and operational expenses. While there is limited scope for optimizing upfront infrastructure costs, the project's lifetime offers opportunities for optimization in OPEX, considering that the polymer is consumed over 3 to 6 years. This strategy involves prioritizing small and mobile facilities, leveraging knowledge of specific reservoir targets for polymer injection. This standardization of engineering and materials streamlines the mounting of modules and allows for a focused approach to infrastructure optimization. The Grimbeek Field case study demonstrates how this approach has significantly increased the return on investment by identifying sweet spots of by-passed oil in the fluvial system using reservoir simulation. Modular mobile polymer injection units were installed in each of these sweet spots. Reservoir simulation reveals that only 38% of the reservoir affected by polymer injection produces more than 60% of the incremental oil. In less than two years, the Grimbeek Field witnessed a production increase from 4100 barrels of oil per day (BOPD) in 2019 to over 9700 BOPD, representing 23% of the total Manantiales Behr production. This successful implementation is expected to deliver 60% of the project's net present value within the next 10 months, effectively rationalizing operational expenditure. The concept of distributed polymer injection is a game-changer in polymer flooding, as it enables a high recovery factor to be achieved within shorter timeframes, reducing implementation time, without significantly increasing operational expenditures or infrastructure footprint. Furthermore, the lifting cost (including polymer, operation, and additional opex for production treatment) (usd/boe) is slightly lower than water injection. Moreover, this approach has prompted a shift in polymer developments globally, with other companies adopting the distributed polymer injection concept and those previously relying on centralized infrastructure now transitioning to this approach. The strategy is applicable to many mature fields, offering improved efficiency and speed across the entire value chain: 1) constructing small polymer injection units off-site, 2) mounting modular installations on-site, 3) implementing relatively short injection cycles (3 to 6 years) with rationalized OPEX, and 4) focusing on cluster production while moving the PIUs to the next targeted area.
- South America (1.00)
- North America > United States (0.94)
- Asia > Middle East > UAE > Abu Dhabi Emirate > Abu Dhabi (0.16)
- South America > Argentina > Patagonia > Golfo San Jorge Basin (0.99)
- Asia > Thailand > Kamphaeng Phet > Block L10/43 > Sirikit Field (0.99)
- South America > Suriname (0.91)
Sustained Annulus Pressure: A Case Study into the Application and Integration of Distributed Optical Fiber Sensing
Webster, Michael James (Expro) | Fiorilo, Elena (Expro) | Salamanca, Maria Eugenia (YPF) | Lopez, Andrea Cristina (YPF) | Orlandi, Carlos Pedro Rodolfo (YPF) | Urmantseva, Lena (AP Sensing)
Abstract Distributed Fiber Optic Sensing (DFOS) allowed us to continuously gather information behind casing, while changing the wells surface conditions. The objective of this case study is to identify the potential causes of the sustained annulus pressure using distributed optical data, integrated it with conventional well information to help define remedial action. The sensing fiber was deployed utilising fiber-enabled slickline allowing the measurement of the whole well over the duration of the survey. Conventional memory Gamma Ray, CCL, Pressure and Temperature sensors were also run on the fiber slickline. A program consisting of an initial baseline, a sequence of bleed off, shutin and production periods were used to create measurable events for the fiber to detect over a 7 hour survey period. With the integration of the information provided by the memory tools, it is possible to determine the location of the sustained pressure contribution and the fluid behavior related to the pressure and temperature changes. The combination of simple data acquisition and rapid processing at wellsite ensured data quality and enabled the option of potential remediation during the same visit to the well. This case study from South America highlights the application of this service in a remote wellsite location with sustained casing pressure issues, the authors concluded that the contribution point was located at the Rayoso Formation and the entry point was the 9 5/8" shoe. Liquid dropout effects during the production phase were confirmed with pressure indications from the memory gauge at the bottom of the fiber. DFOS enabled slickline provides information that allows potential remediation during the same well visit. This case study presents a simple deployment and interpretation methodology reducing time and costs and bringing fiber technology to a mass market. Partnering with key suppliers to simplify the process, helped to make fiber a routine part of an integrated surveillance service.
- North America (0.93)
- South America > Argentina > Mendoza Province (0.35)
- Geophysics > Seismic Surveying (0.48)
- Geophysics > Borehole Geophysics (0.46)
- South America > Argentina > Mendoza > Rayoso Formation (0.99)
- South America > Argentina > Mendoza > Neuquen Basin (0.99)
Summary Vaca Muerta is main UCR in Argentina and most of the concessions in country, drill horizontal wells with lateral lengths (landing point to well TD) of 2500-2800 m. Loma Campana Project developed strategy to develop complex areas by changing well architecture and methodology to drill wells with lateral lengths >4000 m. The team evaluated the feasibility of the project by generating potential well scenarios, prepared specific procedures and documentation during the Planning Phase and defined the Engineering and tools required to drill. Team executed pilot wells and immediately optimized results to massify development with new architecture.
- South America > Argentina > Neuquén Province > Neuquén (0.88)
- South America > Argentina > Patagonia Region (0.66)
- South America > Argentina > Patagonia > Neuquén > Neuquen Basin > Vaca Muerta Field > Vaca Muerta Shale Formation (0.94)
- South America > Argentina > Patagonia > Neuquén > Neuquen Basin > Quintuco Formation (0.94)
- Well Drilling > Pressure Management (1.00)
- Well Drilling > Drilling Operations > Directional drilling (1.00)
- Reservoir Description and Dynamics (1.00)