A Thorough Investigation into the Transient-Pressure Data from Horizontal Oil Wells Equipped With Electrical Submersible Pumps

2017 ◽  
Author(s):  
H. A. Al-Khaldi ◽  
O. H. Al-Obathani ◽  
N. M. Anisur Rahman
Keyword(s):  
Oil Wells ◽  
Pressure Data ◽  
Transient Pressure ◽  
Electrical Submersible Pumps

An ESP Production Optimization Algorithm Applied to Unconventional Wells

2021 ◽  
Author(s):  
Fernando Bermudez ◽  
Noor Al Nahhas ◽  
Hafsa Yazdani ◽  
Michael LeTan ◽  
Mohammed Shono
Keyword(s):  
Gas Production ◽  
Oil Wells ◽  
Production Optimization ◽  
Operating Conditions ◽  
Tight Oil ◽  
Daily Production ◽  
Free Gas ◽  
Maximum Production ◽  
Electrical Submersible Pumps ◽  
High Production

Abstract The objectives and Scope is to evaluate the feasibility of a Production Maximization algorithm for ESPs on unconventional wells using projected operating conditions instead of current ones, which authors expect will be crucial in adjusting the well deliverability to optimum frequencies on the rapidly changing conditions of tight oil wells. Actual production data for an unconventional well was used, covering from the start of Natural Flow production up to 120 days afterwards. Simulating what the production would be if a VFD running on IMP Optimization algorithms had been installed, new values for well flowing pressures were calculated, daily production scenarios were evaluated, and recommended operating frequencies were plotted. Result, observations, and conclusions: A. Using the Intelligent Maximum Production (IMP) algorithm allows maximum production from tight oil wells during the initial high production stage, and the prevention of gas-locking at later stages when gas production increases. B. The adjustment of frequency at later stages for GOR wells is key to maintaining maximum production while controlling free gas at the intake when compared against controlling the surface choke. Novel/additive information: The use of Electrical Submersible Pumps for the production of unconventional wells paired with the use of a VFD and properly designed control algorithms allows faster recovery of investment by pumping maximum allowable daily rates while constraining detrimental conditions such as free gas at the intake.

scholarly journals The Effect of Rheology of Viscoelastic Polymer on Pressure Transient Response in Near-Wellbore Regions

Geofluids ◽  
2021 ◽  
Vol 2021 ◽  
pp. 1-12
Author(s):  
Jia Zhang ◽  
Shiqing Cheng ◽  
Jie Zhan ◽  
Qi Han
Keyword(s):  
Shear Thickening ◽  
Shear Thinning ◽  
Polymer Flooding ◽  
High Shear ◽  
Pressure Data ◽  
Transient Pressure ◽  
Pressure Derivative ◽  
Shear Rates ◽  
Viscoelastic Polymer ◽  
Thickening Behavior

Viscoelastic polymer solution shows shear thinning behavior at low shear rates and shear thickening behavior at high shear rates in reservoirs. However, models that ignored shear thickening behavior were commonly employed to interpret transient pressure data derived from tested wells in viscoelastic polymer flooding systems; although, viscoelastic polymer solutions show shear thickening behavior in the near-wellbore region due to high shear rate. To better characterize the oilfield with pressure transient analysis in viscoelastic polymer flooding systems, we developed a numerical model that takes into account both shear thinning behavior and shear thickening behavior. A finite volume method was employed to discretize partially differential flow equations in a hybrid grid system including PEBI mesh and Cartesian grid, and the Newton-Raphson method was used to solve the fully implicit nonlinear system. To illustrate the significance of our model, we compared our model with a model that ignores the shear thickening behavior by graphing their solutions on log-log plots. In the flow regime of near-wellbore damage, the pressure derivative computed by our model is distinctly larger than that computed by the model ignoring shear thickening behavior. Furthermore, the effect of shear thickening behavior on pressure derivative differs from that of near-wellbore damage. We then investigated the influence of shear thickening behavior on pressure derivative with different polymer injection rates, injection rates, and permeabilities. The results can provide a benchmark to better estimate near-wellbore damage in viscoelastic polymer flooding systems. Besides, we demonstrated the applicability and accuracy of our model by interpreting transient pressure data from a field case in an oilfield with viscoelastic polymer flooding treatments.

scholarly journals Lab-Supported Hypothesis and Mathematical Modeling of Crack Development in the Fluid-Soaking Process of Multi-Fractured Horizontal Wells in Shale Gas Reservoirs

Energies ◽  
2020 ◽  
Vol 13 (5) ◽  
pp. 1035
Author(s):  
Zhiyong Huang ◽  
Boyun Guo ◽  
Rashid Shaibu
Keyword(s):  
Crack Propagation ◽  
Shale Gas ◽  
Oil Wells ◽  
Pressure Data ◽  
Fracturing Fluid ◽  
Well Productivity ◽  
Soaking Time ◽  
Core Samples ◽  
Inflow Performance ◽  
Optimum Water

The objective of this study is to develop a technique to identify the optimum water-soaking time for maximizing productivity of shale gas and oil wells. Based on the lab observation of cracks formed in shale core samples under simulated water-soaking conditions, shale cracking was found to dominate the water-soaking process in multi-fractured gas/oil wells. An analytical model was derived from the principle of capillary-viscous force balance to describe the dynamic process of crack propagation in shale gas formations during water-soaking. Result of model analysis shows that the formation of cracks contributes to improving well inflow performance, while the cracks also draw fracturing fluid from the hydraulic fractures and reduce fracture width, and consequently lower well inflow performance. The tradeoff between the crack development and fracture closure allows for an optimum water-soaking time, which will maximize well productivity. Reducing viscosity of fracturing fluid will speed up the optimum water-soaking time, while lowering the water-shale interfacial tension will delay the optimum water-soaking time. It is recommended that real-time shut-in pressure data are measured and shale core samples are tested to predict the density of cracks under fluid-soaking conditions before using the crack propagation model. This work provides a shut-in pressure data-driven method for water-soaking time optimization in shale gas wells for maximizing well productivity and gas recovery factor.

scholarly journals OPTIMAL OPERATION OF ELECTRICAL POWER GENERATORS FOR OIL WELLS OPERATED BY ARTIFICIAL LIFTING AT RUMILA FIELD

2019 ◽  
Vol 20 (11-12) ◽  
pp. 127-132 ◽  
Author(s):  
Majid Abdulhameed Abdulhy Al-Ali ◽  
V. Yu. Kornilov ◽  
A. G. Gorodnov
Keyword(s):  
Electrical Power ◽  
Oil Production ◽  
Optimal Operation ◽  
Oil Wells ◽  
Oil Field ◽  
Parallel Operation ◽  
Economic Gain ◽  
Power Generators ◽  
Artificial Lift ◽  
Electrical Submersible Pumps

Numerous oil wells within Rumaila field contain Electrical Submersible Pumps (ESPs). ESPs are utilised to maximise the oil production from existing wells by providing artificial lift where pressure is low, which helps maintain oil production levels. The number of ESPs installed throughout the Rumaila. Field is growing consistently to sustain oil field production. Due to the remote locations for each of the ESPs the current strategy is to supply power to ESPs using individual diesel engine generators located at each remote ESP well site. This is an inefficient design, as individual diesel engines are resource intensive due to maintenance and frequent diesel filling. The generators are also a source of significant unreliability causing ESP shutdowns/trips resulting in extended downtime. Given the above a Pre-FEED has been carried out considering supplying ESPs using OHTL’s supplying electrical power from EPP to ESPs in Area C. by uses parallel operation of diesel Generators , we could to constrict 124 from 184 and use 60 only ,by this we get high economic gain and technique, in additional that environmental protection by decreasing pollution.

scholarly journals Construction of a carbonate reservoir model using transient pressure data

2009 ◽  
Vol 36 (6) ◽  
pp. 762-767 ◽  
Author(s):  
Seyed Sadegh Taheri Rudsari ◽  
Mohammad Bagher Ghanizadeh ◽  
Manuchehr Haghighi
Keyword(s):  
Carbonate Reservoir ◽  
Pressure Data ◽  
Transient Pressure ◽  
Reservoir Model

Calibration of High-Resolution Reservoir Models Using Transient Pressure Data

2009 ◽  
Author(s):  
Jong Uk Kim ◽  
Akhil Datta-Gupta ◽  
Roald Brouwer ◽  
Byron Haynes
Keyword(s):  
High Resolution ◽  
Pressure Data ◽  
Transient Pressure ◽  
Reservoir Models
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