The primary function of drilling mud is to lift the drill cut and to avoid problems in drilling hole. The purpose and objective of this study are to determine the ability to lift cutting in oil drilling wells. The method in the cutting process can use in three ways, first is Cutting Transport Ratio (Ft), Cutting Concentration (Ca), and the last is Cutting Carrying Index. The three methods have a standard that must be considered. Drilling mud affects the penetration rate during drilling activities. In drilling operations, a high penetration rate is always desirable. Mud pump as a tool for flowing mud into the wellbore affects the speed of the fluid flow of the mud in the annulus, the flow pattern in the mud circulation, and the ability to lift the cutting in the well while the mud pump specification determines the significant flow rate to circulated in the drilling process. The value of rheology of mud such as plastic viscosity and yield value of mud density also affect the performance of the slurry to become a medium for lifting drill cut. The three methods have a standard that must be considered. Cutting Transport Ratio (Ft) must have a value of > 90%, for the cutting concentration (Ca) method must have a value <5%, and cutting carrying index (CCI) has a value of 1.

The volumetric method is the initial method used in calculating hydrocarbon reserves obtained from the exploration stage obtained geological data from a field in the oil and gas industry. The hydrocarbon reserve calculation obtained from a volumetric method is the result of interpretation data, such as seismic and logging data that have a small range of trust. In this study estimated hydrocarbon reserves in the XY formation gas reservoir using a material balance method or P/Z method in assessing optimism or pessimism of the reserve value generated from a volumetric method. The material balance method or P/Z method was chosen as a reliable method. Because it has better accuracy data such as pressure measurement data, reservoir rock, and fluid analysis data. Cumulative production measurement data compared to interpretation data on a volumetric method. From this research can be concluded that the reserve value produced by the volumetric method is more pessimistic than the reserve value using the material balance method and P/Z method. By knowing pessimism results from the volumetric backup method for the other two methods. it will affect the amount of oil and gas industry reserves so that geological model needs to be done again after more accurate data is obtained.

The well analysed in this paper is A-1 well, T field, located approximately 90 km north of Bali. Reservoir in this field is gas reservoir with sandstone rock formation, one of the problems of A-1 well is sand problem. Due to the sand problem in well A-1, well test analysis must be done first, to see if there is any damage to the formation if the flow rate is increased. Identification of formation damage in a well can be done by doing Pressure Build up test. The method used is pressure build up test by Horner method with Sapphire software v.3.20. The determination of deliverability test was conducted by back pressure test. Given the results of the analysis, the permeability value remains, the value of the skin and reservoir pressure decreased. From the results of the tests, there were no significant changes, indicating no formation damage. The results of the deliverability tests decrease, due to decreased reservoir pressure. Since there is no formation damage, the flow rate can still be increased up to 30% of AOFP.

Well, test pressure and deliverability analysis are carried out to determine permeability (k), skin formation damage factor, initial pressure (Pi), (ΔP skin), investigation radius (ri), the boundary of the reservoir. The results of this work are used to calculate the initial gas reserves by wells and predict production capacity in the wells studied (AOFP). Furthermore, an optimal production plan will be produced to produce the most economical value. The result of this work is the initial pressure value (Pi) which is equal to 862 psi. The skin values of the pressure derivative and Horner Plot methods are -0.214 and -0.232 respectively, the permeability value is 148 and 135 mD, the value of the investigation radius is 2110 ft. The resulting AOFP is 8214 Mscf/D. The calculation of the initial gas reserves by well uses the volumetric method which is equal to 458 MMscf. These results carried out forecasting production performance aims to determine the most optimal production planning. This production plan, the scenario plan are the 1st scenario with a gas rate of 2 MMscf and 2nd scenario uses a compression 50 psi with a gas injection rate of 1 MMScf. Furthermore, the best scenario of this research is the maximum production by using 50 psi injection rate of 1 MMScf.

One EOR injection is polymer injection. In this study we will use FP3300S polymer with a concentration of 500ppm, 750ppm, 1,000ppm, 1,250ppm, 1,500ppm, 1,750ppm, 2,000ppm, 2,250ppm and 2,500ppm. The purpose and objective of this study was to determine the effect of polymer concentration on increasing viscosity, determine the effect of polymer concentration on polymer filtration (compatibility, filtration, screen factor, thermal stability), and to find out how the polymer injection results, the higher the research found. the polymer concentration the higher the viscosity where the highest at the polymer concentration 2,500ppm with 19,38cp, the viscosity required by the polymer as injection liquid is the viscosity of the polymer greater than 2X the viscosity of the oil to be injected, where the oil viscosity is 5,2pp. then while in polymer screening it was found that higher polymer concentrations were not always good for polymer filtration, and polymer injection has been shown to increase recovery factor, recovery factor was obtained at 51.5% water injection and polymer injection was 23.1%, before injection was correct really need to be screened first, to get the most optimal concentration to be injected.