Horizontal well completions in low permeability formations with multistage fracturing have advanced greatly over the last decade. However, achieving an optimal balance between operational and cluster efficiency remains challenging. Several studies across unconventional basins have shown less than 70% productive perforation clusters in plug-and-perf (PnP) completions, highlighting a need to improve cluster efficiency without sacrificing operation efficiency. This paper presents a case study of Wolfcamp horizontal shale wells utilizing degradable diverter particulates to successfully improve cluster efficiency and well production. Degradable diverter was implemented in five of eleven wellsacross three separate padsfor direct comparison. The diverter particulates were pre-tested in the laboratory with source water and formation cuttings samples to determine the dissolution rate and reservoir compatibility. Concentrations and deployment rate of the diverter "pill" were optimized from pressure responses during the job execution to achieve both the desired number of perforations covered and corresponding pressure increase as a leading indicator of improved cluster efficiency. Surface microseismic survey was acquired to further evaluate diverter effectiveness as compared to the offset non-diverter wells. Initial engineering design/modeling targeted 50% to 65% of perforations for diverter coverage. All diverter frac stages pumped to the expected frac design with no screen outs. Post treatment analysis were run between each pad to optimize diverter integrity for further displacement and enhancement of diversion efficiency based on observed pressure build-up. Significant pressure increases pre-and post diverter were observed in 75% of stages. Surface microseismic results measured in the first pad indicated a 50% increase in the number of microseismic events in the well with diverter along with subtle shifts in both frac geometry and orientation. In 90% of stages a noticeable correlation was perceived in surface pressure responses to microseismic events. Wider event distribution post-diversion was also noted in stages with larger surface pressure responses. Production results show wells with diverter average 10% incremental cumulative barrels of oil equivalent (BOE) production at nine totwelve months as compared to offset non-diverter wells. There is a higher prevalence of elevated GOR with the diverter wells. Average incremental oil production during the six to twelve-month time frame is 9%. Incremental impact on individual pads range from neutral to +20% at the same time frame. This paper shares the effective testing strategy to trial intra-stage diversion, engineering design work, application, analysis of diagnostic data and performance of degradable particulates in new unconventional horizontal wells. This paper also incorporates the lessons learned and best practices from field execution, real-time pressure responses, microseismic data, and production signpost results.

As drilling and fracturing operations improve and wells have longer laterals, there is a need to adapt current Coil Tubing Unit Drillout (CTUDO) process to be more fit-for-purpose approach applicable in any area, regardless of lateral length, number of plugs, and reservoir target. This paper presents the CTUDO methodology developed and implemented with case study results on the successful engineering design and implementation of new technologies to improve performance and eliminate large nonproductive time events, via the utilization of a successful, repeatable, and operationally safe process. A thorough evaluation of the CTUDO process was conducted to gain a better understanding of the critical factors that provided the greatest influence on improving performance. The results indicated that the main influencing factors were: wellbore trajectory, plug type, coil tubing size, bottom hole assembly (BHA) selection, fluid rheology QA/QC, real-time modeling, and communication. Rather than instituting and optimizing the critical factors all at once, a piece-by-piece road map was created. Over a five-month trial period, the factors were fully implemented and analyzed. Once the methodology was validated with predictable, repeatable, and successful consistent outcomes, it became the new standard for CTUDO's. Full implementation of this Factory Model CTUDO methodology has been successfully used for over three years and continues to be the standard process. The well performance impact realized by optimizing the main factors, along with other technological advancements has been substantial. Appropriate engineering design led to better understanding the fluid rheology system and optimal chemical usage and dosage during CTUDO's. Coupled with proper CTU size and BHA optimization, pump rate capability and annular velocity are optimized, while minimizing plug debris size, aided in hole cleaning, which lead to greater efficiency. The use of data analytics to identify trends in downhole tool data, used in conjunction with real-time data allowed for procedure optimization. Operational enhancements include removing planned short trips (ST) and effectively eliminating stuck CTU events. Since the inception of this methodology 320+ horizontal wells ranging from 5,000′ to 10,000′+ have been successfully completed, with well plug counts ranging from 19 to 102. Average time savings is shown to be 66%, and average cost savings 61%. In addition, the process has provided additional cost savings benefits and reduced Put-On-Production (POP) cycle times by eliminating the need of dedicated post drillout flowback. This paper details the utilization of a simple, effective method for successfully executing and improving performance on CTUDO's. This paper also incorporates lessons learned and best practices from field execution, real-time data analysis and interpretation, and technology implementation. Furthermore, this methodology is designed to be a plug-and-play system, with minimal or no modifications needed to be applied in any unconventional basin across the world.

This study provides the first account of the occurrence of Botrytis crown rot of lettuce in New Mexico. Lettuce plants affected by Botrytis crown rot displayed symptoms that included necrotic lesions on leaves, crown rot, and collapse of leaves at the crown. Severely affected plants were covered with grayish mycelium mats and spore masses. Black sclerotia were also found on several symptomatic plants. Based on morphological features and molecular analysis, the causal agent of Botrytis crown of lettuce in New Mexico was identified as B. cinerea. Although lettuce is a minor crop in New Mexico, the finding of Botrytis crown rot underlines the need of regularly monitoring lettuce fields to detect emerging pathogens so that appropriate control measures may be designed to mitigate the impact of these pathogens in production fields.

There are many challenges to be overcome when drilling lateral sections in the Wolfcamp horizon of the Delaware Basin. These include wellbore instability, formation heterogeneity, low rate of penetration (ROP), poor weight transfer and drill bit damage. Downhole data was captured in order to provide insight into these challenges. A Downhole Dynamics Tool (DDT) was used to capture the data necessary to investigate the drilling performance challenges. The data collected was downhole weight on bit (DHWOB) and torque, downhole bending moments and tool face, annular and bore pressure readings, and downhole vibrations. The analysis of these data provided insights into the effectiveness of connection and WOB zeroing practices, clarity about recurrent bit nozzle plugging and bit damage, and a better understanding of wellbore tortuosity and effective WOB transfer. The DDT was used on multiple wells, in memory mode and in real-time. On the initial trial well, the tool was run in memory-only mode due to drilling system requirements; subsequently real-time data was additionally used to further optimize drilling performance. After retrieving the data and analyzing trends from the initial memory-only runs, the following could be highlighted: Using downhole pressure and WOB, it was shown that the bit was still on-bottom during connections. Pipe stretch calculations were performed and matched with downhole data in order to verify minimum stick up length required to effectively pick the bit off-bottom during connections. This allowed the development and adoption of a new standard for connection practices.The downhole bending moment data identified the presence of wellbore rugosity driven by several factors, including magnitude of the steering force from the rotary steerable system (RSS) steering unit.Downhole WOB data showed that weight transfer efficiency was not 100%. The loss of WOB is inferred to be caused by factors such as hole rugosity, inconsistently zeroed surface WOB and friction losses.The data obtained about the causes of bit plugging, bit coring damage, and wellbore rugosity, was used to redesign and optimize future bits to be used in lateral drilling operations. Some of the recommended enhancements included changes in nozzle orientation, improved impact resistance for inner cutting structure and improved gauge pad design. Use of downhole data identified factors affecting drilling performance which differed from what was initially believed. The use of downhole data enabled changes in operational practices, drill string and bottom hole assembly (BHA) design, bit design, and drilling parameter roadmaps. The lessons learned and best practices from the data analysis were successfully transferred and implemented across all development areas in the Permian Basin.

The selection of perforation zones in unconventional reservoirs can be very challenging. Great strides have been made by the integration of both engineering and geological data. However, a successful perforation zone selection methodology in one Basin might not be successful in another. This paper presents a pilot study on a perforation zone selection and zonal contribution in a vertical well in the Midland Basin. Reservoir characteristics as well as the geomechanical properties of a formation are important in the selection of optimum locations for limited entry perforations. In this work, several data sets, including openhole logs, radioactive tracer logs, amount of proppant pumped, PVT sampling, and 3D fracture modeling were integrated. Additionally, temperature logs were used to identify zonal contributions during the early flowing period. Results from this work indicate that closure stress is the dominant parameter greatly affecting the fracture initiation and growth in the observed well while both high and low brittleness sections were observed similar behavioris of hydraulic fracture failure. Learnings from radioactive proppant tracers and 3D fracture modeling efforts helped to identify the importance of closure stress in addition to brittleness in perforation placement identification. Temperature log interpretations were correlated with proppant tracers and fracture modeling which qualitatively indicates that the Lower Spraberry and Wolfcamp B formations are big contributors to production and thus good potentials targets for horizontal wells.