The channel fracturing technique combines fracture modeling, materials and pumping methods to generate a network of highly conductive channels within the proppant pack. These channels aim at expediting the delivery of hydrocarbons from the reservoir to the wellbore (Gillard et al., 2010). This paper provides a comprehensive summary of the implementation of this novel technique in the Burgos basin, Mexico North. The Eocene Yegua formation in the Palmito field near Reynosa, Mexico was selected for this study. This formation comprises sandstone layers with average permeability of 0.5 mD and Young’s modulus in the order of 2.5 Mpsi. Key historical issues for the stimulation of this formation using conventional fracturing materials are limited polymer recovery and the consequential fracture conductivity impairment. Use of resin-coated proppants has also been implemented to prevent proppant flowback from these operations. Gas production, treating pressure and polymer recovery data from a twelve-well campaign in the Palmito field (six wells treated via channel fracturing, six offset wells treated conventionally and aiming for similar fracture geometry) are summarized in the manuscript. Results indicate that the implementation of the channel fracturing technique improved fluid and polymer recovery, thus leading to increases in initial gas production by 32% and 6-month cumulative gas production by 19%. Such improvements in production were obtained with 50% less proppant per stage and smaller proppant particles. These observations are consistent with the hypothesis that the channel fracturing technique promotes the decoupling of fracture conductivity from proppant pack permeability. Positive features that were also observed during this campaign such as absence of proppant flowback issues without the use of resin-coated sand and non-occurrence of near-wellbore screen-outs are also reported and discussed. The study concluded that the channel fracturing technique is a viable alternative to conventional fracturing methods for the stimulation of wells in the Burgos basin.
This paper describes the practical applicacion of a method known as Flowing Gas Material Balance FGMB (L. Mattar and Mcneil, 1997) for reserve's estimation using bottomhole flowing pressure data in two dry gas fields in Mexico. The main purpose of this work is to apply the method in real cases having enough data and make a comparison with other standard methods of reserves estimation (J. Lee, 1996 and G.J. DeSorcy, 1994) such as Volumetric, Decline Curve Analysis, Conventional Material Balance and Numerical Simulation to see the results and validate the efficacy of its application.There are some premises should be considered before its application that will be explained, besides the advantages and results of this comparison which showed differences no greater than 10% with respect to the method more trustable to report reserves for these reservoirs.
This paper describes several engineering workflows as part of the Digital Oil Field Solution implemented in a Gas Asset where there are different technical challenges. The main objective of this technology application is to revert the production decrease and optimize the operations in the asset, enhancing the capabilities of monitoring and surveillance and also to improve the analysis capability, taking the advantage of the benefits of the real time instrumentation, data integration, data quality, in addition to the definition of a complete automation process for all the information in different frequencies covering all the stages such as: data acquisition, transmission, integration, until monitoring and surveillance. With the implementation of operational and engineering workflows better efficiencies can be achieved, improving in time of response, and the decision making process, having tools for early anomaly detection to take proactively corrective actions that minimize the deferred production and losses.
This paper describes the practical applicacion of a method known as Flowing Gas Material Balance FGMB (L. Mattar and Mcneil, 1997) for reserve's estimation using bottomhole flowing pressure data in two dry gas fields in Mexico. The main purpose of this work is to apply the method in real cases having enough data and make a comparison with other standard methods of reserves estimation (J. Lee, 1996 and G.J. DeSorcy, 1994) such as Volumetric, Decline Curve Analysis, Conventional Material Balance and Numerical Simulation to see the results and validate the efficacy of its application. There are some premises should be considered before its application that will be explained, besides the advantages and results of this comparison which showed differences no greater than 10% with respect to the method more trustable to report reserves for these reservoirs.
Commonly when fields are operated, there are several challenges to face and make profitable the operations, from the reservoir perspective one of the key challenges is when we have undesirable fluids that can cause cost in the operations and make more complex the production. This is the case when we have water or gas production in an oil reservoir or water production of a gas reservoir. First of all the productivity on the well can be affected, the recovery factor, and all the impact that can cause in the operations, costs, etc. When we talk about water production there are several possible sources associated to this problem, in the literature (Fig.1) there are at least ten know possible sources can cause water production, one of these problems considered is the coning phenomenon (Fig. 2). Eventually, the water or gas breaks through into the well and water from the aquifer and/or gas from the gas cap is produced along with oil. The water or gas production increases progressively after breakthrough time and may reduce significantly the crude oil production. Understand all the parameters that affect or influence coning is very important and also to be able to select the proper methods to analyze and mitigate it. In this paper the water or gas coning is examined covering some analytical methods and numerical reservoir simulation workflow applied to different reservoirs of the Veracruz Basin to understand the behavior of the wells, estimate the critical rates, the breakthrough time and establish a proper plan to this wells to avoid or mitigate the water and gas production; to reach this a numerical simulation workflow is proposed, examples and comparison is included when the wells are above or below critical rates.
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