scholarly journals Incremental and acceleration production estimation and their effect on optimization of well infill locations in tight gas reservoirs

2021 ◽  
Author(s):  
Atheer Dheyauldeen ◽  
Omar Al-Fatlawi ◽  
Md Mofazzal Hossain
Keyword(s):  
Transient Flow ◽  
Development Planning ◽  
Main Role ◽  
Gas Reservoirs ◽  
Type Curves ◽  
Field Development ◽  
Drilling Performance ◽  
Well Location ◽  
Infill Drilling ◽  
Tight Formations

AbstractThe main role of infill drilling is either adding incremental reserves to the already existing one by intersecting newly undrained (virgin) regions or accelerating the production from currently depleted areas. Accelerating reserves from increasing drainage in tight formations can be beneficial considering the time value of money and the cost of additional wells. However, the maximum benefit can be realized when infill wells produce mostly incremental recoveries (recoveries from virgin formations). Therefore, the prediction of incremental and accelerated recovery is crucial in field development planning as it helps in the optimization of infill wells with the assurance of long-term economic sustainability of the project. Several approaches are presented in literatures to determine incremental and acceleration recovery and areas for infill drilling. However, the majority of these methods require huge and expensive data; and very time-consuming simulation studies. In this study, two qualitative techniques are proposed for the estimation of incremental and accelerated recovery based upon readily available production data. In the first technique, acceleration and incremental recovery, and thus infill drilling, are predicted from the trend of the cumulative production (Gp) versus square root time function. This approach is more applicable for tight formations considering the long period of transient linear flow. The second technique is based on multi-well Blasingame type curves analysis. This technique appears to best be applied when the production of parent wells reaches the boundary dominated flow (BDF) region before the production start of the successive infill wells. These techniques are important in field development planning as the flow regimes in tight formations change gradually from transient flow (early times) to BDF (late times) as the production continues. Despite different approaches/methods, the field case studies demonstrate that the accurate framework for strategic well planning including prediction of optimum well location is very critical, especially for the realization of the commercial benefit (i.e., increasing and accelerating of reserve or assets) from infilled drilling campaign. Also, the proposed framework and findings of this study provide new insight into infilled drilling campaigns including the importance of better evaluation of infill drilling performance in tight formations, which eventually assist on informed decisions process regarding future development plans.

Reservoir Management Paradigm Shift Upon Successful Recent Drilling Well of Sungai Gelam Field, Jambi

2021 ◽  
Author(s):  
R. Rahadian
Keyword(s):  
Reservoir Characterization ◽  
Water Injection ◽  
Reservoir Management ◽  
Velocity Model ◽  
Management Approach ◽  
Field Development ◽  
Well Location ◽  
New Findings ◽  
Infill Drilling ◽  
Water Cut

Sungai Gelam structure is one of the backbone brownfield structures supporting Jambi field oil productions. Geologically, Sungai Gelam is highly related to structural-trap type which commonly occur in Air Benakat Formation, as main hydrocarbon producer. There are total 29 wells in Sungai Gelam penetrate the Air Benakat Formation, some extend through the Talang Akar Formation. Re-evaluation of the last two years (S-25 and S-26) of infill drilling program indicate unsatisfactory production results. The latest two wells which have been drilled in 2018 have been used to update velocity model, facies model and the reservoir simulation. Considering tremendous depth uncertainty on the western part of the field, several new infill well locations have now been planned to recover bypassed oil within the existing wells, to acquire new velocity data and to be water injection conversion-ready location for the productive reservoirs. The overall reservoir management approach has been thought to be the most benign option for the field. Well S-27 has been approved in 2019 as one of the best infill locations. The well location bears the lowest risks and produces a naturally flowing 286 BOPD far beyond the predicted oil target. It also yields a 2040 psia virgin formation pressure oil column from new N1 sand productive target which have not fully developed by the existing wells. The discovery leads to a speedy work over program at the existing nearby well, S-23, and produces 212 BOPD with 0% water cut. Two infill wells acceleration have been proposed for year 2020. The field’s reservoir characterization study has been yet again recycled by the new target oil. The field has now been under drastic redevelopment plan with more detailed reservoir flow unit modeling, new data acquisition, PSDM seismic reprocessing, new infill wells and step-out wells targeting deeper reservoirs. Sungai Gelam field development shows strong fundamental yet versatile field reservoir management rendering to real-time drilling data. New findings have been seamlessly adjusted in the framework and acted upon accordingly. Production of S-27 and S-23 well then accelerate additional two drilling wells which drilled in 2020.

scholarly journals Transient-Flow Modeling of Vertical Fractured Wells with Multiple Hydraulic Fractures in Stress-Sensitive Gas Reservoirs

2019 ◽  
Vol 9 (7) ◽  
pp. 1359 ◽  
Author(s):  
Ping Guo ◽  
Zhen Sun ◽  
Chao Peng ◽  
Hongfei Chen ◽  
Junjie Ren
Keyword(s):  
Hydraulic Fracture ◽  
Transient Flow ◽  
Superposition Principle ◽  
Pressure Profile ◽  
Stress Sensitivity ◽  
Hydraulic Fractures ◽  
Transient Pressure ◽  
Gas Reservoirs ◽  
Type Curves ◽  
Vertical Well

Massive hydraulic fracturing of vertical wells has been extensively employed in the development of low-permeability gas reservoirs. The existence of multiple hydraulic fractures along a vertical well makes the pressure profile around the vertical well complex. This paper studies the pressure dependence of permeability to develop a seepage model of vertical fractured wells with multiple hydraulic fractures. Both transformed pseudo-pressure and perturbation techniques have been employed to linearize the proposed model. The superposition principle and a hybrid analytical-numerical method were used to obtain the bottom-hole pseudo-pressure solution. Type curves for pseudo-pressure are presented and identified. The effects of the relevant parameters (such as dimensionless permeability modulus, fracture conductivity coefficient, hydraulic-fracture length, angle between the two adjacent hydraulic fractures, the difference of the hydraulic-fracture lengths, and hydraulic-fracture number) on the type curve and the error caused by neglecting the stress sensitivity are discussed in detail. The proposed work can enrich the understanding of the influence of the stress sensitivity on the performance of a vertical fractured well with multiple hydraulic fractures and can be used to more accurately interpret and forecast the transient pressure.

scholarly journals Fracture networks in Rotliegend gas reservoirs of the Dutch offshore: implications for reservoir behaviour

2000 ◽  
Vol 79 (1) ◽  
pp. 45-57 ◽  
Author(s):  
B.D.M. Gauthier ◽  
R.C.W.M. Franssen ◽  
S. Drei
Keyword(s):  
Fracture Network ◽  
Development Planning ◽  
Small Scale ◽  
List Type ◽  
Gas Reservoirs ◽  
Positive Role ◽  
Field Development ◽  
Fracture Systems ◽  
Reservoir Flow ◽  
Gas Fields

AbstractFracture systems of Rotliegend gas fields in and at the margins of the northern Broad Fourteens Basin in the Dutch offshore are described in terms of orientation, frequency, origin and type, and in relation to larger-scale structures. First, fracture data collected from core and image logs have been corrected to account for the bias related to the 1-D sampling. Second, these results were integrated with data on fracture cements and diagenesis in order to assess the timing of the fracture network development.On the basis of their regional extent three phases of fracturing and four orientation trends can be distinguished in the basin: (1)at Triassic times and related to early diagenesis and burial, NW-SE to NNW-SSE and NE-SW to ESE-WNW particulate-shear fractures developed;(2)during the Mid-Kimmerian and related to the main burial stage, shear-related and dilational-shear-fault-related fracturing occurred parallel with larger-scale faults;(3)during the Cretaceous and related to uplift, NW-SE and NE-SW joints propagated; a regional joint system developed outside the Jurassic rift basin, preferentially oriented E-W to ESE-WNW; these joints have not been dated accurately.The fault-related shear fractures tend to compartmentalise the reservoirs, whereas the regional joints tend to enhance reservoir flow properties. These fracture systems are thought to play a negative or positive role, respectively, but only in fields with poor reservoir quality. Consequently, in such cases small-scale fractures should be taken into account in field development planning.

scholarly journals Analysis of Flow Behavior for Acid Fracturing Wells in Fractured-Vuggy Carbonate Reservoirs

2018 ◽  
Vol 2018 ◽  
pp. 1-20 ◽  
Author(s):  
Mingxian Wang ◽  
Zifei Fan ◽  
Xuyang Dong ◽  
Heng Song ◽  
Wenqi Zhao ◽  
...  
Keyword(s):  
Composite System ◽  
Numerical Solutions ◽  
Transient Flow ◽  
Flow Behavior ◽  
Outer Region ◽  
Carbonate Reservoirs ◽  
Single Fracture ◽  
Specific Flow ◽  
Type Curves ◽  
Acid Fracturing

This study develops a mathematical model for transient flow analysis of acid fracturing wells in fractured-vuggy carbonate reservoirs. This model considers a composite system with the inner region containing finite number of artificial fractures and wormholes and the outer region showing a triple-porosity medium. Both analytical and numerical solutions are derived in this work, and the comparison between two solutions verifies the model accurately. Flow behavior is analyzed thoroughly by examining the standard log-log type curves. Flow in this composite system can be divided into six or eight main flow regimes comprehensively. Three or two characteristic V-shaped segments can be observed on pressure derivative curves. Each V-shaped segment corresponds to a specific flow regime. One or two of the V-shaped segments may be absent in particular cases. Effects of interregional diffusivity ratio and interregional conductivity ratio on transient responses are strong in the early-flow period. The shape and position of type curves are also influenced by interporosity coefficients, storativity ratios, and reservoir radius significantly. Finally, we show the differences between our model and the similar model with single fracture or without acid fracturing and further investigate the pseudo-skin factor caused by acid fracturing.

Artificial Lift Strategy Selection Within Field Development Planning (Russian)

2015 ◽  
Author(s):  
A. V. Alferov ◽  
A. G. Lutfurakhmanov ◽  
K. V. Litvinenko ◽  
S. E. Zdolnik
Keyword(s):  
Development Planning ◽  
Strategy Selection ◽  
Field Development ◽  
Artificial Lift
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