Understanding of Vertical and Horizontal Pressure Barriers in the Naturally Fractured Carbonate Field

2021 ◽  
Author(s):  
Abdulmalik Ibragimov ◽  
Nurbolat Kalmuratov
Keyword(s):  
Late Devonian ◽  
Growth Stages ◽  
Rock Property ◽  
Field Development ◽  
Sequence Stratigraphic ◽  
Sector Model ◽  
Fractured Carbonate ◽  
Horizontal Pressure ◽  
Simulation Results ◽  
Depositional Cycles

Abstract The Karachaganak field is a massive reef carbonate structure. The main reservoir is of the late Devonian-Carboniferous age, where sequence stratigraphic cycles of progradation and aggradation defining the growth stages of the carbonate build-up have been revealed. Vertical and horizontal semiconductive barriers was identified in the reservoir during the field development. It was assumed that these barriers are located at the boundaries of the changing depositional cycles, which took place during the reef structure growth. According to the simulation results on a sector model of the reservoir it was determined that the pressure barriers can be developed due to different fracture intensities observed in the reservoir and not because of rock property as such. The reason for the different fracture densities may be associated with compaction during primary diagenesis and may have a sync-depositional nature, which can be seen on carbonate structure outcrops.

The Research on Effect Factors of the Polymer Flooding in Low Permeability Reservoir of Daqing Oilfield

2011 ◽  
Vol 383-390 ◽  
pp. 3809-3813
Author(s):  
Yong Li Wang ◽  
Tao Li ◽  
Zhi Guo Fu ◽  
Shu Xia Liu ◽  
Bai Lin Yu ◽  
...  
Keyword(s):  
Oil Recovery ◽  
Injection Rate ◽  
Polymer Flooding ◽  
Low Permeability ◽  
Effect Factors ◽  
Field Development ◽  
Low Permeability Reservoir ◽  
Well Pattern ◽  
Simulation Results ◽  
Enhance Oil Recovery

The pilot block is a heterogeneous reservoir with low permeability which is only 100-200(mD). Polymer flooding will be used to enhance oil recovery (EOR). Therefore, some experiment will be carried out in this pilot block .According to the simulation results, we can infer the effect factors of the polymer flooding such as concentration, injection rate, slug amounts, and well pattern. It gives us effective information for the field development plan.

scholarly journals Economic Evaluation of Y Gas Field Development Using Reservoir Simulator

2018 ◽  
Vol 1 (3) ◽  
Author(s):  
Anita Theresa Panjaitan ◽  
Rachmat Sudibjo ◽  
Sri Fenny
Keyword(s):  
Development Strategy ◽  
Reservoir Simulation ◽  
Gas Field ◽  
Field Development ◽  
Development Scenarios ◽  
Black Oil ◽  
Simulation Results ◽  
Reservoir Simulation Model ◽  
Attractive Case ◽  
Reservoir Simulator

<p>Y Field which located around 28 km south east of Jakarta was discovered in 1989. Three wells have been drilled and suspended. The initial gas ini place (IGIP) of the field is 40.53 BSCF. The field will be developed in 2011. In this study, reservoir simulation model was made to predict the optimum development strategy of the field. This model consisted of 1,575,064 grid cells which were built in a black oil simulator. Two field development scenarios were defined with and without compressor. Simulation results show that the Recovery Factor at thel end of the contract is 61.40% and 62.14% respectively for Scenarios I and II without compressor. When compressor is applied then Recovey Factor of Scenarios I and II is 68.78% and 74.58%, correspondingly. Based on the economic parameters, Scenario II with compressor is the most <br />attractive case, where IRR, POT, and NPV of the scenario are 41%, 2.9 years, and 14,808 MUS$.</p>

scholarly journals Significance of root hairs at the field scale – modelling root water and phosphorus uptake under different field conditions

2019 ◽  
Vol 447 (1-2) ◽  
pp. 281-304 ◽  
Author(s):  
S. Ruiz ◽  
N. Koebernick ◽  
S. Duncan ◽  
D. McKay Fletcher ◽  
C. Scotson ◽  
...  
Keyword(s):  
Uptake Rate ◽  
Large Scale ◽  
Phosphorus Uptake ◽  
Root Hairs ◽  
P Uptake ◽  
Growth Stages ◽  
Field Scale ◽  
Soil P ◽  
Simulation Results ◽  
The Impact

Abstract Background and aims Root hairs play a significant role in phosphorus (P) extraction at the pore scale. However, their importance at the field scale remains poorly understood. Methods This study uses a continuum model to explore the impact of root hairs on the large-scale uptake of P, comparing root hair influence under different agricultural scenarios. High vs low and constant vs decaying P concentrations down the soil profile are considered, along with early vs late precipitation scenarios. Results Simulation results suggest root hairs accounted for 50% of total P uptake by plants. Furthermore, a delayed initiation time of precipitation potentially limits the P uptake rate by over 50% depending on the growth period. Despite the large differences in the uptake rate, changes in the soil P concentration in the domain due to root solute uptake remains marginal when considering a single growth season. However, over the duration of 6 years, simulation results showed that noticeable differences arise over time. Conclusion Root hairs are critical to P capture, with uptake efficiency potentially enhanced by coordinating irrigation with P application during earlier growth stages of crops.

Prediction of Dynamical Changes Hydrogen Sulfide Concentration During South-West Gissar Gas-Condensate Fields Development

2021 ◽  
Author(s):  
Elena Descubes ◽  
Svetlana Yessalina ◽  
Amir Kuvanyshev ◽  
Anna Zhelezova ◽  
Dana Shaikhina ◽  
...  
Keyword(s):  
Hydrogen Sulfide ◽  
Data Interpretation ◽  
Fracture Network ◽  
Gas Condensate ◽  
Sulfide Concentration ◽  
Field Development ◽  
Compositional Model ◽  
Content Change ◽  
Fractured Carbonate ◽  
Sour Gas

Abstract An unexpected raise of hydrogen sulfide levels during development of several gas condensate fields in Southwestern Gissar, producing from naturally fractured carbonate reservoirs, observed within a year, lead to necessity of full scale comprehensive investigation. For planning of effective mitigation strategy important questions related to the reasons of hydrogen sulfide level growth and prediction of its further behavior have been addressed in the present study. The entire investigation process encompassed both theoretical and practical parts. Theoretical part covered evaluation of sour gas sources that was crucial in respect to selection of conceptual methodology for predictions. All possible contributing sources including primary and secondary have been investigated to discern the causes and consequences of hydrogen sulfide occurrence. Practical component of the study employed cut to edge technologies tested and implemented in reservoir simulation. Based on conceptual constraints with the use of existing field data, interpretation results and regional knowledge basin and 3D static models with fracture network have been developed. Obtained modeling results have been integrated into compositional model, allowing to predict with applied uncertainty analyses further H2S content change during field development.

High Resolution Correlation of Sequence Stratigraphy to Stipulate Further Hidrocarbon Prospect in A Mature Field : Case Study of Limau Field, South Sumatera Basin

2021 ◽  
Author(s):  
P. Suseno
Keyword(s):  
High Resolution ◽  
Depositional Environment ◽  
Middle Miocene ◽  
Well Log ◽  
Field Development ◽  
Sequence Stratigraphic ◽  
Sediment Deposits ◽  
Order Sequence ◽  
Rms Amplitude

The Limau Trend Structure is located in the South Sumatera Basin of Indonesia. The main reservoir in this field is the Talang Akar Formation which is deposited in a fluvial complex that changes gradually into a shallow marine depositional environment in a transgressive phase of 3rd order sequence. The sediment deposit was developed from the Late Oligocene to Middle Miocene. A high-resolution sequence stratigraphic interpretation of the 3rd to 4th order was interpreted from the subsurface data (core and well log) combined with the outcrop observation that resulted in a comprehensive input for building a geological model. Based on this framework, the transgressive phase series in each parasequence set produces restricted sediment deposits that have the potential for stratigraphic traps. On the other hand, the amalgamated sands of the regression phase will be related to the structural traps. The RMS amplitude volume from seismic multi attributes analysis shows that the facies is changing with the reservoir distribution. The seismic attributes such as VpVs indicate a hydrocarbon presence. The combination of all data reveals that the stratigraphic traps are the main trapping mechanism in the Limau field. The field development works are now focusing in the northern area, on the transgressive phase of the 4th order parasequence set. It composes of a fluvial complex cycle that has a high potential for a virgin geometrically restricted (lense shaped) reservoir rather than well-connected and sand-rich maximum regressive reservoir facies. This transgressive phase reservoir of parasequence set (4th order) at the Northern Belimbing Field was proven by 2 (two) recently drilled wells. Both wells showed very good hydrocarbon indications and produced oil with an initial rate of 174 bopd & 1265 bopd respectively. These results confirmed the oil prospectivity within the transgressive phase of the 4th order parasequence set at the Northern Limau Trend. The initial resources estimation in the Northern Belimbing Field contains 65 MMBO. This is very promising for the development of the Belimbing Field, Limau Trend.

A New Approach to Simulation of Wax Precipitation During Cold Water Injection in Carbonate Reservoir of Kharyaga Oilfield

2021 ◽  
Author(s):  
Yuri Mikhailovich Trushin ◽  
Anton Sergeevich Aleshchenko ◽  
Oleg Nikolaevich Zoshchenko ◽  
Mark Suleimanovich Arsamakov ◽  
Ivan Vasilevich Tkachev ◽  
...  
Keyword(s):  
Cold Water ◽  
Water Injection ◽  
Carbonate Reservoir ◽  
Hot Water ◽  
Reservoir Rock ◽  
Laboratory Studies ◽  
Wax Deposition ◽  
Field Development ◽  
Sector Model ◽  
The Impact

Abstract The paper describes a methodology for assessing the impact of wax deposition in reservoir oil during cold water injection into heterogeneous carbonate reservoir D3-III of the Kharyaga field. The main goal is to determine the optimal amount of hot water that must be injected before switching to cold water without affecting the field development. The paper presents the results of laboratory studies to determine the thermophysical properties of oil, samples of net reservoir and non-reservoir rock, as well as the results of laboratory studies to determine the conditions and nature of wax deposition in oil when the temperature and pressure conditions change. Calculations were carried out to describe the physical model of oil displacement by water of various temperatures. A series of synthetic sector model runs was performed, which includes the average properties of the selected reservoir and the results of laboratory studies in order to determine the effect of cold water injection on the development performance.

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