Investment Planning in Oil Production Enhancement Projects in Ukraine Based on Joint Usage of 3D Modelling and SPE-PRMS Reserves Classification

2021 ◽  
Author(s):  
Nazarii Hedzyk ◽  
Roman Malyk ◽  
Serhii Tyvonchuk ◽  
Volodymyr Vaskiv ◽  
Oksana Vanchak ◽  
...  
Keyword(s):  
Development Strategy ◽  
Field Data ◽  
Material Balance ◽  
Oil Production ◽  
Hydrodynamic Modeling ◽  
High Potential ◽  
Stochastic Methods ◽  
Modeling Tools ◽  
Field Development ◽  
Geological Information

Abstract Most of the discovered oil fields in Ukraine entering a declining production stage. Many of these assets have good potential for production increasing and require investments. The risks of such investments are related to the uncertainty of geological information, production data, and the total amount of reserves and resources. This paper describes the study of the joint use of 3D hydrodynamic modeling and reserves estimation according to the SPE-PRMS classification, which together allowed to assess and significantly reduce investment risks for oil production enhancement projects. The use of 3D modeling is one of the key elements during field exploration and production, because of coordination of all available geological and field data it is often possible to discover new, previously unknown features of the geological structure and identify high potential areas to increase production. In this paper petrophysical, geological and hydrodynamic modeling tools and material balance method have been used to consolidate existing geological and field data and create 3D model of the field in Western oil and gas bearing region of Ukraine. Also, for uncertainty analysis of the initial hydrocarbons in-place and IOR project investment presentation the SPE-PRMS classification was used. Comprehensive usage of material balance tools, field development history analysis, well performance changes, and fluid properties behavior revealed inconsistencies in the geological data and hypothesized the existence of a gas cap in the oil deposit and identify a faults system through the reservoir. After well logging these hypotheses has been confirmed, which allowed achieving a good history match of the model for the entire field and each well. Based on the matched model, a comprehensive field development strategy was proposed, which also considered all existing limitations related to production and infrastructure issues. The best scenario of field development was selected, according to the results of the economic assessment in terms of investment attractiveness. Based on the created 3D geological model, hydrocarbons reserves and resources were estimated using deterministic and stochastic methods and have been classified according to the SPE-PRMS. Reserves categories were assessed by the degree of commercial maturity of the project based on ten possible field development scenarios and high potential zones for infill drilling, plays exploration, and IOR project implementation was selected. The integrated approach to the field development strategy assessment and the input data uncertainties allowed to consider all available geological information and field data to create a comprehensive pilot investment IOR project. The proposed approach allows to solve complex problems of potential investments risks assessment and reduction in IOR projects and discover new assets' potential on the example of a complex field in the inner zone of the Pre-Carpathian Depression.

Stochastic Methods for Evaluating the Effectiveness of Arctic Shelf Field Development Strategy (Russian)

2011 ◽  
Author(s):  
Kristina Sevastianova ◽  
Mikhail Kuznetsov ◽  
Peter Tarasov ◽  
Vladimir Zilber ◽  
Sergey Nekhaev
Keyword(s):  
Development Strategy ◽  
Arctic Shelf ◽  
Stochastic Methods ◽  
Field Development

Successful Unconventional Fracturing Tight and Highly Laminated Silicilyte Reservoir Leading to Economic Field Development

2021 ◽  
Author(s):  
Alexey Moiseenkov ◽  
Dmitrii Smirnov ◽  
Abdullah Al Hadhrami ◽  
Pankaj Agrawal ◽  
Amira Harrasi ◽  
...  
Keyword(s):  
Development Strategy ◽  
Oil Production ◽  
Commercial Production ◽  
Full Field ◽  
Field Development ◽  
Chemical Tracers ◽  
Vertical Permeability ◽  
To Come ◽  
Development Approach ◽  
Sonic Logging

Abstract South Oman contains several tight silicilyte reservoirs with significant locked hydrocarbon volumes. Successful hydraulic fracturing is key for unlocking commercial production. Low production rates coupled with fast declines have remained a challenge and a new economically attractive development scheme was required. Through integrated re-evaluation of the geology and reservoir, a modified frac approach was designed to create more connectivity to the reservoir height, using an unconventional frac design and frac fluids plus over-flush. Poor well productivity in tight silicilyte reservoir can be explained by low permeability of 0.001-0.1 mD and laminated texture with almost zero vertical permeability. Fit for purpose modelling was performed to assess the forecasting range for sub-surface uncertainties and frac parameters. One of the key changes for a successful development strategy was to place a higher number of fracs to overcome the extreme lamination. [1] It was observed that the "conventional" fracturing approach inaccurately assumed higher vertical fracture coverage of the reservoir and that the guar fluid used was much more damaging due to low recovery after frac clean-up. Fifteen unconventional fracs were pumped successfully with over-flush pumping technique. To understand if this new unconventional approach was effective in overcoming the extreme lamination required additional understanding of fractures geometry and orientation. To confirm fracture dimensions and flowing heights; a set of radioactive, chemical tracers and logging activities were completed. Flowback results showed that the unconventional frac [3] fluid used, was relatively easy to recover from formation and better cleaning-up of fractures can be achieved. This led to successful well clean-up compared to previous wells in the same field and confirmed better fracs clean up. Initial production results confirmed at least double well initial productivity, which should lead to better stable oil production from the field. Radioactive tracers logging, Sonic logging and Spectrum Noise Logging (SNL) confirmed mechanical and conductive fracture heights. Sonic logging also confirmed frac orientation. Oil and water dissolvable tracers confirmed fractures clean up from water and oil production intervals. Full geological and reservoir understanding, out of box thinking in frac technology allowed the asset team to come up with an unconventional development approach to improve commercial production from tight silicilyte reservoirs. The new frac approach included unconventional frac design and fluids, and execution using over flush and resulted into unlocking significant reserves. A more economic full field development is being planned and replication of the new frac approach is already ongoing in other fields.

Justification of Well Type and Design Depending on Depletion Mechanism of High-Viscosity Oil Production

2014 ◽  
Vol 698 ◽  
pp. 674-678
Author(s):  
Vasilina Khanzhina ◽  
Aleksei Kovalev ◽  
Aleksei Zinoviev
Keyword(s):  
Development Strategy ◽  
Oil Production ◽  
High Viscosity ◽  
Field Development ◽  
High Viscosity Oil

While choosing an optimal field development strategy it is necessary to take into account the possible effects of oil structural-mechanical qualities. The presented methods allow estimating the effect of structural-mechanical qualities of the production of oil with high levels of asphaltene and tarry substances. After completing all calculations and designing, a parameter set is created for optimal depletion mechanisms of the production of nonlinear high-viscosity non-Newtonian oil.

Stochastic Methods for Evaluating the Effectiveness of Arctic Shelf Field Development Strategy

2011 ◽  
Author(s):  
Kristina Sevastianova ◽  
Mikhail Kuznetsov ◽  
Peter Tarasov ◽  
Vladimir Zilber ◽  
Sergey Nekhaev
Keyword(s):  
Development Strategy ◽  
Arctic Shelf ◽  
Stochastic Methods ◽  
Field Development

Short Term Injection Re-Distribution STIR: Real-Time Waterflood Optimization Technique Using Advanced Data Analytics

2021 ◽  
Author(s):  
Gaurav Modi ◽  
Manu Ujjwal ◽  
Srungeer Simha
Keyword(s):  
Real Time ◽  
Data Analytics ◽  
Optimization Technique ◽  
Material Balance ◽  
Oil Production ◽  
Data Driven ◽  
Petroleum Engineering ◽  
Short Term ◽  
Injection Water ◽  
Facility Level

Abstract Short Term Injection Re-distribution (STIR) is a python based real-time WaterFlood optimization technique for brownfield assets that uses advanced data analytics. The objective of this technique is to generate recommendations for injection water re-distribution to maximize oil production at the facility level. Even though this is a data driven technique, it is tightly bounded by Petroleum Engineering principles such as material balance etc. The workflow integrates and analyse short term data (last 3-6 months) at reservoir, wells and facility level. STIR workflow is divided into three modules: Injector-producer connectivity Injector efficiency Injection water optimization First module uses four major data types to estimate the connectivity between each injector-producer pair in the reservoir: Producers data (pressure, WC, GOR, salinity) Faults presence Subsurface distance Perforation similarity – layers and kh Second module uses connectivity and watercut data to establish the injector efficiency. Higher efficiency injectors contribute most to production while poor efficiency injectors contribute to water recycling. Third module has a mathematical optimizer to maximize the oil production by re-distributing the injection water amongst injectors while honoring the constraints at each node (well, facility etc.) of the production system. The STIR workflow has been applied to 6 reservoirs across different assets and an annual increase of 3-7% in oil production is predicted. Each recommendation is verified using an independent source of data and hence, the generated recommendations align very well with the reservoir understanding. The benefits of this technique can be seen in 3-6 months of implementation in terms of increased oil production and better support (pressure increase) to low watercut producers. The inherent flexibility in the workflow allows for easy replication in any Waterflooded Reservoir and works best when the injector well count in the reservoir is relatively high. Geological features are well represented in the workflow which is one of the unique functionalities of this technique. This method also generates producers bean-up and injector stimulation candidates opportunities. This low cost (no CAPEX) technique offers the advantages of conventional petroleum engineering techniques and Data driven approach. This technique provides a great alternative for WaterFlood management in brownfield where performing a reliable conventional analysis is challenging or at times impossible. STIR can be implemented in a reservoir from scratch in 3-6 weeks timeframe.

Multistage Openhole Completion Using Integrated Dynamic Diversion Frac Technique in Highly Depleted Well: First Successful Application in West Kuwait Field

2021 ◽  
Author(s):  
Abdullah Abu-Eida ◽  
Salem Al-Sabea ◽  
Milan Patra ◽  
Bader Akbar ◽  
Kutbuddin Bhatia ◽  
...  
Keyword(s):  
Best Practice ◽  
Treatment Options ◽  
High Energy ◽  
Lessons Learned ◽  
High Potential ◽  
Fracture Plane ◽  
Fluid Loss ◽  
Field Development ◽  
Two Fluids

Abstract The Minagish field in West Kuwait is a high potential field which poses several challenges in terms of hydrocarbon flow assurance through highly depleted tight carbonate intervals with uneven reservoir quality and curtailed mobility. These conditions have shifted the field development from vertical to horizontal wellbore completions. Achieving complete wellbore coverage is a challenge for any frac treatment performed in a long openhole lateral with disparities in reservoir characteristics. The fluid will flow into the path of least resistance leaving large portions of the formation untreated. As a result, economic fracturing treatment options dwindle significantly, thus reservoir stimulation results are not always optimum. A multistage fracturing technique using Integrated Dynamic Diversion (IDD) has been performed first time in West Kuwait field well. The process uses active fluid energy to divert flow into a specific fracture point in the lateral, which can initiate and precisely place a fracture. The process uses two self-directed fluid streams: one inside the pipe and one in the annulus. The process mixes the two fluids downhole with high energy to form a consistent controllable mixture. The technique includes pinpoint fluid jetting at the point of interest, followed by in-situ HCL based crosslinked systems employed for improving individual stage targets. The IDD diversion shifts the fracture to unstimulated areas to create complex fractures which increases reservoir contact volume and improved overall conductivity in the lateral. The kinetic and chemical diversion of the IDD methodology is highly critical to control fluid loss in depleted intervals and results in enhanced stimulation. Pumping a frac treatment in openhole without control would tend to initiate a longitudinal fracture along the wellbore and may restrict productivity. By using specialized completion tools with nozzles at the end of the treating string, a new pinpoint process has been employed to initiate a transverse fracture plane in IDD applications. Proper candidate selection and fluid combination with in-situ crosslink acid effectively plug the fracture generated previously and generate pressure high enough to initiate another fracture for further ramification. By combining these processes into one continuous operation, the use of wireline/coiled tubing for jetting, plug setting and milling is eliminated, making the new multistage completion technology economical for these depleted wells. The application of the IDD methodology is a fit-for-purpose solution to address the unique challenges of openhole operations, formation technical difficulties, high-stakes economics, and untapped high potential from intermittent reservoirs. The paper will present post-operation results of this completion from all fractured zones along the lateral and will describe the lessons learned in implementation of this methodology which can be considered as best practice for application in similar challenges in other fields.

Offshore Gas Field Development Strategy and Flow Assurance Prediction and Optimization in Harsh Environment

2018 ◽  
Author(s):  
Humoud Almohammad ◽  
Abdullah Al-Derbass ◽  
Abdulaziz Alsubaie ◽  
Mohammed Bumajdad ◽  
Abdulaziz Al-Khamis ◽  
...  
Keyword(s):  
Development Strategy ◽  
Harsh Environment ◽  
Flow Assurance ◽  
Gas Field ◽  
Field Development

scholarly journals Reducing Hydrocarbon in Place Uncertainty in Akasia Bagus Structure as Potential Field and Redevelopment Review

2020 ◽  
Vol 2 (3) ◽  
Author(s):  
Tri Handoyo ◽  
Suryo Prakoso
Keyword(s):  
Development Strategy ◽  
Material Balance ◽  
Production Optimization ◽  
Balance Method ◽  
Water Influx ◽  
Natural Flow ◽  
Production Economic ◽  
Conventional Material ◽  
Original Oil In Place ◽  
Material Balance Method

<em>The success of the discovery of new structure Akasia Bagus with potential L layer in 2009 at PT Pertamina EP's Jatibarang Field was followed up by the drilling infill wells with Plan of Development (POD) mechanism which is currently in the process of drilling the last well. The basis of the L layer hydrocarbon calculation in place on the POD is a static analysis. The wells currently produced are still able to flow with natural flow and enough production data since 2009 this structure was found. This study will present an analysis of production in the L layer of Akasia Bagus structure for Original Oil In Place (OOIP) updates using the conventional material balance method and then carry out the best development strategy to optimize oil production. Economic analysis is also carried out for reference in making decision on which scenario to choose. The conventional material balance method gets an OOIP value of 17.36 MMSTB, with the drive energy ratio being 5:3:2 for water influx : fluid expansion : gas cap expansion. Three (3) production optimization scenarios were analyzed, the results showed that the addition of 2 infill wells reached Recovery Factot (RF) of oil up to 23% of OOIP, minimal water production and attractive economic results.</em>

scholarly journals Integrated Halo Model And Hydrodynamic Simulation For Optimization Oil Production In Crystalline Fractured Reservoirs

2021 ◽  
Author(s):  
Hung Vo Thanh ◽  
Kang-Kun Lee
Keyword(s):  
Oil Recovery ◽  
History Matching ◽  
Fractured Reservoirs ◽  
Petroleum Industry ◽  
Oil Production ◽  
Modelling And Simulation ◽  
Development Plan ◽  
Sweep Efficiency ◽  
Field Development ◽  
The World

Abstract Basement formation is known as the unique reservoir in the world. The fractured basement reservoir was contributed a large amount of oil and gas for Vietnam petroleum industry. However, the geological modelling and optimization of oil production is still a challenge for fractured basement reservoirs. Thus, this study aims to introduce the efficient workflow construction reservoir models for proposing the field development plan in a fractured crystalline reservoir. First, the Halo method was adapted for building the petrophysical model. Then, Drill stem history matching is conducted for adjusting the simulation results and pressure measurement. Next, the history-matched models are used to conduct the simulation scenarios to predict future reservoir performance. The possible potential design has four producers and three injectors in the fracture reservoir system. The field prediction results indicate that this scenario increases approximately 8 % oil recovery factor compared to the natural depletion production. This finding suggests that a suitable field development plan is necessary to improve sweep efficiency in the fractured oil formation. The critical contribution of this research is the proposed modelling and simulation with less data for the field development plan in fractured crystalline reservoir. This research's modelling and simulation findings provide a new solution for optimizing oil production that can be applied in Vietnam and other reservoirs in the world.

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