Since its recent detection in July 2021, the reintroduction of African swine fever (ASF) in the Dominican Republic (DR) has generated much discourse on various measures for its effective control. Strategies range from complete depopulation of the swine population, as was done in 1978, to a system of passive surveillance with endemicity, with many in-between. Currently, ASF-decision makers need a peer evaluation and comparison and contrast of these potential strategies that incorporates both private and public perspectives. To achieve this, we used strengths, weaknesses, opportunities, and threats (SWOT) analysis to evaluate three different theoretical ASF control scenarios with the aim of contributing evaluations of alternatives strategies to mitigate the epidemic's impact. These included total depopulation of all pigs in the DR, partial depopulation, and continuation of current control measures. Relevant experts from the DR private swine industry were identified through “snowball sampling” techniques. Five experts completed the SWOT questionnaire and additional questions considering aspects of financial cost, social impact, feasibility, animal welfare, and regional policy. The summarized responses were presented to the full group of experts initially nominated for final review and later to representatives of the DR government. The SWOT analysis highlighted that although there are certain benefits associated with each of the proposed strategies, there are also important drawbacks and disadvantages for all. This analysis is a tool for facilitating cooperating between the private-public industries, and ultimately it supports the development of strategies that will reduce ASF burden in the DR in a way suitable for all relevant stakeholders.
This paper presents an operator's approach to optimize future well performance by fully integrating all the data captured in the Vaca Muerta shale. Based upon insight from the study, the operator needed to make more informed asset management decisions, understand the interaction between the shale and the hydraulic fracture network, and improve economics. Data were captured from several wells, both vertical and horizontal. The data incorporated into the study included fieldwide seismic data, as well as mineralogical, geomechanical, well plan, drilling, completion, microseismic monitoring, and production data from the wells.The project comprised one case history involving the hydraulic fracture stimulation treatment of a cluster of horizontal wells. Microseismic hydraulic fracture monitoring (HFM) was utilized to "track" the development of the hydraulic fractures in real time as they propagated throughout the formation. The stimulation activity from the well was monitored from a horizontal array placed in a horizontal lateral drilled parallel to the target well but landed~80 m shallower in the vertical section.An integrated unconventional-reservoir-specific workflow was utilized to develop and evaluate the completion strategies for the subject well. First, a fieldwide 3D static geologic model was constructed using the aforementioned data to determine the best reservoir and completion qualities of the Vaca Muerta formation. Next, the model was used to develop the completion strategy, including staging, perforation scheme, stimulation design, etc., for the wells. The completion strategy and stimulation design were performed utilizing an automated, rigorous, and efficient multistaging algorithm (completion advisor). This enabled targeting the reservoir section having the best reservoir and completion qualities for the stimulation treatments. The stimulation designs were performed using a state-of-the-art unconventional hydraulic fracture simulator that properly simulates the complex fracture propagation in shale reservoirs, including the explicit interaction of the hydraulic fractures to the pre-existing natural fissures in the formation and performs automatic gridding of the created complex fractures to rigorously model the production response from the tridimensional fracture network.A comparison between the microseismic fracture geometry to the planned fracture geometry is revealing; it shows that the application of this new technology can identify some of the complications and
The South Region of PEMEX in Mexico produces 530,000 bopd from mostly mature, naturally-fractured carbonate reservoirs. The majority of the well interventions in the area present complications, due to a combination of extreme operational conditions, variety of reservoir rocks and fluid environments, and complex well configurations required to produce from large intervals in different flow units, many supported by active aquifers and secondary gas caps, that eventually reduce the production of oil as the water production and gas production increase. Rigless stimulation and maintenance well operations have been recognized for decades as efficient and cost-effective production enhancement enablers in the area. As the fields mature and the well interventions become more challenging, there is a higher demand on the operator side to successfully pinpoint the intervals and execute treatments that overcome unknown downhole parameters with confidence, maximizing success and avoiding additional remedial work. A new approach, incorporating real-time, coiled tubing-deployed, fiber optics monitoring, was implemented in three well interventions in southern Mexico. These included: (a) the isolation of a high-water producing interval in a low-pressure reservoir using an inflatable packer; (b) a matrix stimulation requiring the accurate placement of fluids and diversion stages; and (c) the perforation and testing of several intervals in a gas injector well. Real-time down-hole measurements of performance have been found to be an excellent option to improve the success rate in the well interventions in southern Mexico, allowing capturing unique quantitative feedback from the well, to be able to act with a greater degree of precision to increase production. Coiled tubing-deployed fiber optics proved to help the operator to improve efficiency and to optimize intervention performance with confidence in real time.
One of the components in PEMEX's strategy to offset the natural decline of some of Mexico's giant fields consists in the implementation of technological advances and best practices for mature fields. About 70% of the hydrocarbon produced in Mexico originates in naturally fractured, depleted carbonate reservoirs, with active aquifers and secondary gas caps, which makes it difficult to maintain production levels and increase recovery factors. To optimize the reservoir-well-facilities systems, in 2006 PEMEX established, in cooperation with service companies, multidisciplinary productivity teams to generate portfolios of opportunities in all its production assets nationwide. The selection and optimization of stimulation and matrix-acidizing treatments were identified as critical enablers for production enhancement. The stimulation designs have evolved in several directions, including the utilization of energized fluids, the introduction of emulsified acids, and the application of high-dissolution systems for high-temperature wells. Fluid placement techniques for selective stimulation have improved with the assistance of high-hydraulic-impact tools, inflatable packers, downhole real-time monitoring, and chemical-mechanical self-diverting fluids with degradable fibers to treat high-temperature formations. These improvements and evolutions have brought about solutions to historical problems and made it possible to optimize stimulation treatments in complex carbonate reservoirs with superior production results, including: 1) identifying natural-fracture patterns in low-productivity areas to increase the well-formation contact by acid fracturing; 2) treating and optimizing wells with severe gas breakthrough with strong diversion mechanisms to temporarily isolate the gas channels and stimulate the producing zones; 3) employing selective diversion fluids and non-reactive systems to break emulsions and water blockages in wells with high water cuts; and 4) applying state-of-the art fluids to maximize productivity from new discoveries. The application of PEMEX's Well Productivity strategy is successfully contributing to maintaining Mexico's hydrocarbon production levels. For example, in PEMEX's South Region, it is estimated that 50,000 BOPD is the average incremental production per year obtained by solving a historical scale and organics deposition problem, and that 35,000 BOPD is the average incremental obtained from new wells by successfully removing and bypassing the drilling-induced damage. This paper discusses the production enhancement workflows, milestones, examples, results, lessons learned and strategies established to meet the production targets in various naturally fractured carbonate fields in Mexico.
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