Hugoton Gas Log Report

Upon evaluating the properties of the well we were able to successfully generate a logical interpretation that can lead to potential economic reservoirs in the formation. The application of porosity, water saturation, permeability, and volumetric concentration mineral constituents and evaluation of shale zones allowed for a much better log interpretation. We aim to look for zones with high porosity, low water saturation, and low shale concentration. Porosity allows us to determine the amount of void space within the rock and is instrumental in determining the amount of potential fluid within the rock. A high porosity indicates there is plenty of open space within the zone and may indicate presence of hydrocarbons. A low water saturation simply

We were tasked with evaluating several properties of the wells to formulate a plan to perforate potential zones of interest. We began by importing the data onto TechLog and evaluated the borehole condition for only the well with the caliber log and confirmed its integrity and we noted it to be in good condition. We also determined the type of drilling mud, WBM, due to the presence of SP log and formation water had higher salt concentration. Next with several given parameters we began by formulating the temperature equation and implementing it onto TechLog and acquired our first log. The Temperature logs can be seen in Figure 2 and Figure 3 on Page 4. We proceeded to estimate the volumetric concentration of shale using the linear model and with the help of TechLog plotted the results, which can be seen in Figure 4 and noted that the formation lacked consistency and we knew the presence of shale would be an issue. Our team then created a Pickett Plot: porosity vs. deep resistivity to estimate connate water salt concentration. The mud filtrate salt concentration of the mud was determined using Archie’s equation and the salinity was found using Arp’s equation. To estimate the volumetric concentration of mineral constituents we converted density porosity to bulk density and photoelectric factor to volumetric photoelectric factor and used the Quanti.Elan function. Total porosity was determined from Quanti Elan function as well as initial water saturation and initial hydrocarbon saturation. We calculated grain density by multiplying concentration of minerals by density. A trendline equation was fitted to the cross plot of permeability vs. porosity and we used it to determine permeability. Once we finished calculating and interpreting the logs and plots, we came to the conclusion to perforate three zones: 2690-2720, 2740-2760, and 2810-2840. These zones were