The Marmaton formation is a large limestone reservoir straddling the Oklahoma and Texas Panhandle. This oil laden formation is a significant resource with potential recovery exceeding 88 million BOE, making it an attractive target for many operators. Similar to the Bakken, it was once considered unviable as an unconventional carbonate play due to complexity and associated production costs. With the application of modern horizontal drilling and fracturing techniques, operators are dispelling this notion. To date more than 1,300 vertical and approximately 300 horizontal wells have been drilled in this play. Although the first horizontal was completed back in 1992, full development of the Marmaton has been relatively slow. Until recently, much of it was considered marginally economic, but this is changing with the application of innovative technologies that unlock and extract commercial volumes of hydrocarbons from the reservoir. The standard well completion is typically an open hole, multistage (OHMS) completion system that utilizes packers for isolation and fracturing sleeves for stage diversion. This technology facilitates placement of stimulation treatments in one continuous pumping operation. Once the stimulation operation is complete, the well can be immediately flowed back and put on production resulting in efficient operations. This paper will discuss how one of the more prolific operators in the play is developing its acreage by prudently employing new technologies. These new technologies and advancements include the following: degradable balls, water-soluble tracers, radioactive tracers, and high-rate water fractures. Each will be discussed in detail to help paint a picture of how this particular operator is leading the industry in unlocking the full potential of the Marmaton. To assist in the ongoing development of this unconventional play, theoretical and practical lessons will be highlighted.

An operator working in the STACK and Mississippi Lime plays of the Mid-Continent region in the United States is developing its acreage with the use of open hole multistage (OHMS) completion systems. This paper will detail new technologies and advancements that are providing enhanced economic benefits and enabling the operator to unlock the full potential of the targeted formations. The operator holds one of the largest acreage positions in the Mid-Continent region and in 2014 had operated or participated in approximately 170 horizontal wells. This operator approached its development with the goal of reducing completion costs; bringing completion costs in line with estimated completion costs; reducing health, safety and environment (HSE) exposure, while reducing cycle time; and preserving estimated ultimate recovery (EUR) of its assets. Some of the new technologies and advancements to achieve these goals include: changing core completion methods, radioactive tracers, dissolvable balls, high-rate water stimulation, extended reach laterals, microseismic analysis, water-soluble tracers, oil-soluble tracers, stage spacing and statistical analyses. These new technologies and advancements adopted by implementing OHMS completion systems provided the operator with significant cost savings when compared to previous wells completed in the region using cemented liner plug-and-perf techniques. Lessons learned from each well were applied to future wells and the operator realized further cost savings as it continued development of the region using OHMS completion systems. These cost reductions were achieved while preserving the EUR of the assets, increasing the economic viability of the operations. The technologies, methods and procedures will be presented in this paper to help paint a picture of how this particular operator is leading the way in reducing completion costs and increasing reserves. The details provided will show how OHMS technology is a cost-effective option for operators drilling and completing horizontal wells in the Mid-Continent region of the United States and provide strategies that can be applied in other formations around the world.

An operator working in Oklahoma's STACK play continues to analyze its completion program in an effort to identify the optimal balance between cost-effectiveness and production. A recent study of field results from four pads with two different completion methods on each pad, shows a difference in fracture performance between the two methods, as well as resulting production. Each of the four well pads was developed with one ball-activated uncemented multistage completions and a cemented liner completion using either sliding sleeves or plug-and-perf. The methods on each pad targeted the same horizon in the STACK play, which is made up of multiple formations. The wells on each pad were stimulated with the same treatment program, and the performance of the wells was analyzed using microseismic, sidewall cores and extensive logs. Additionally some of the pads were also tested with diverter. Daily OWG rates were also reviewed, and a cost comparison between the two completions on each pad was conducted. The STACK play is predominantly completed using plug-and-perf methods. These wells have long laterals and are typically stimulated with large amounts of fluid and proppant. All the wells in this study were completed with common stimulation programs for the area. Despite the typical estimated frac length, three of the subject wells experienced offset stimulation interference from offsetting wells or pads. These "frac hits" contributed negatively on the producing wells for a period of time. On all the pads, the wells completed using uncemented multistage completion systems had lower CAPEX Quicker completions and easier millouts helped contribute to the lower upfront CAPEX. The uncemented multistage wells also flowed back initially at higher rates. This paper compares a new completion method attempted in one of the most active plays in the United States. As well as the diagnostic, completion and cost comparisons, the impacts of a "frac hit" on producing wells and suggestions to reduce negative outcomes from the hits will be discussed.

Evaluation of completion techniques continues to help in cost reduction and optimization practices. The objective of this project is to evaluate completions within Oklahoma in the STACK (Sooner Trend, Anadarko Basin, and Canadian and Kingfisher counties), comparing several types of technology and optimization methods implemented within this play. Changes to completion practices are driven by cost reduction and production needs. When evaluating a newly implemented technique, a "science well" is often selected to run a multitude of diagnostics to verify the effectiveness of the change. The dataset in this study goes beyond the concept of a single well, or several well analysis, and focuses on approximately 50 wells in this play. Wells are categorized based on completion practices and data was gathered based on completion diagnostics. A macroscopic production analysis was completed to complement the diagnostic results. As with any study of this magnitude, there are several variables to capture and take into consideration while evaluating the diagnostic and production data. Wells in this study are categorized to maximize the number of unchanged variables. Observations were made on the overall stimulation coverage of each treatment interval evaluated, isolation between stages completed, and trends in production. Several examples of diagnostic data are presented as case histories in addition to the categorized data set. The STACK is one of the four most prolific plays currently being drilled and completed in the United States. This is the largest case history published on wells completed in the STACK that utilizes an integrated daily production and diagnostic approach. The dataset and case histories in this paper provide valuable insight for operators and service companies who are completing wells in this play.

An operator working in the STACK and Mississippi Lime plays of the Mid-Continent region in the United States is developing its acreage with the use of open hole multistage (OHMS) completion systems. This paper will detail new technologies and advancements that are providing enhanced economic benefits and enabling the operator to unlock the full potential of the targeted formations. The operator holds one of the largest acreage positions in the Mid-Continent region and in 2014 had operated or participated in approximately 170 horizontal wells. This operator approached its development with the goal of reducing completion costs; bringing completion costs in line with estimated completion costs; reducing health, safety and environment (HSE) exposure, while reducing cycle time; and preserving estimated ultimate recovery (EUR) of its assets. Some of the new technologies and advancements to achieve these goals include: changing core completion methods, dissolvable balls, microseismic analysis, water-soluble tracers, oil-soluble tracers, stage spacing and statistical analyses. These new technologies and advancements adopted by implementing OHMS completion systems provided the operator with significant cost savings when compared to previous wells completed in the region using cemented liner plug-and-perf techniques. Lessons learned from each well were applied to future wells and the operator realized further cost savings as it continued development of the region using OHMS completion systems. These cost reductions were achieved while preserving the EUR of the assets, increasing the economic viability of the operations. The technologies, methods and procedures will be presented in this paper to help paint a picture of how this particular operator is leading the way in reducing completion costs and increasing reserves. The details provided will show how OHMS technology is a cost-effective option for operators drilling and completing horizontal wells in the Mid-Continent region of the United States and provide strategies that can be applied in other formations around the world.