scholarly journals Influence of well management in the development of multiple reservoir sharing production facilities

2020 ◽  
Vol 75 ◽  
pp. 70
Author(s):  
João Carlos von Hohendorff Filho ◽  
Denis José Schiozer
Keyword(s):  
Oil Recovery ◽  
Development Project ◽  
Gas Production ◽  
Oil Field ◽  
The Other ◽  
Dynamic Flow ◽  
Field Development ◽  
Light Oil ◽  
Multiple Reservoir ◽  
The Impact

Well prioritization rules on integrated production models are required for the interaction between reservoirs and restricted production systems, thus predicting the behavior of multiple reservoir sharing facilities. This study verified the impact of well management with an economic evaluation based on the distinct prioritizations by reservoir with different fluids. We described the impact of the well management method in a field development project using a consolidated methodology for production strategy optimization. We used a benchmark case based on two offshore fields, a light oil carbonate and a black-oil sandstone, with gas production constraint in the platform. The independent reservoir models were tested on three different approaches for platform production sharing: (Approach 1) fixed apportionment of platform production and injection, (Approach 2) dynamic flow-based apportionment, and (Approach 3) dynamic flow-based apportionment, including economic differences using weights for each reservoir. Approach 1 provided the intermediate NPV compared with the other approaches. On the other hand, it provided the lowest oil recovery. We observed that the exclusion of several wells in the light oil field led to a good valuation of the project, despite these wells producing a fluid with higher value. Approach 2 provided the lower NPV performance and intermediate oil recovery. We found that the well prioritization based on flow failed to capture the effects related to the different valuation of the fluids produced by the two reservoirs. Approach 3, which handled the type of fluids similarly to Approach 1, provided a greater NPV and oil recovery than the other approaches. The weight for each reservoir applied to well prioritization better captured the gains related to different valuation of the fluids produced by the two reservoirs. Dynamic prioritization with weights performed better results than fixed apportionment to shared platform capacities. We obtained different improvements in the project development optimization due to the anticipation of financial returns and CAPEX changes, due mainly from adequate well apportionment by different management algorithm. Well management algorithms implemented in traditional simulators are not developed to prioritize different reservoir wells separately, especially if there are different economic conditions exemplified here by a different valuation of produced fluids. This valuation should be taken into account in the short term optimization for wells.

scholarly journals INVESTIGATION OF THERMAL PROPERTIES OF RESERVOIR ROCKS AT DIFFERENT SATURATION

2020 ◽  
Author(s):  
Sudad H Al-Obaidi ◽  
Kamensky IP ◽  
Smirnov VI
Keyword(s):  
Thermal Properties ◽  
Oil Recovery ◽  
Oil And Gas ◽  
Thermal Characteristics ◽  
Gas Production ◽  
Oil Field ◽  
Oil And Gas Production ◽  
Field Development ◽  
Water Saturated ◽  
And Control

Oil and gas production using formation thermal stimulation or treatment represents one of the main enhanced oil recovery methods. In this study the thermal properties of rocks and their relationship to the nature of rock saturation were investigated.The method, experimental setup, and results of studying the thermal characteristics of fine - and medium-grained highly porous sandstones at their different saturation are presented. The highest values of thermal diffusivity, thermal conductivity and heat capacity correspond to water-saturated samples, smaller values correspond to oil-saturated ones and the lowest values corresponds to dry (extracted) samples. The obtained data can be used in the selection of the technology of thermal formation stimulation on the reservoir and control over the process of oil field development.

Feasibility Study on the Implementation of CO2-EOR Coupled with Sequestration in Trinidad via Reservoir Simulation

2014 ◽  
Author(s):  
J.. Narinesingh ◽  
D. V. Boodlal ◽  
D.. Alexander
Keyword(s):  
Primary Production ◽  
Oil Recovery ◽  
Net Present Value ◽  
Fluid Model ◽  
Gas Production ◽  
Economic Feasibility ◽  
Utilization Rate ◽  
Optimum Number ◽  
Field Development ◽  
Co2 Eor

Abstract The paper seeks to assess the technical and economic feasibility of implementing carbon dioxide enhanced oil recovery (CO2 EOR) in Trinidad and Tobago from flue gas production whilst mitigating the effect of greenhouse gases via CO2 sequestration. An existing power plant in Trinidad was selected as the CO2 source. As such, actual CO2 volumes and properties were found and used in this analysis. However, a hypothetical field was chosen as the appropriate sink, which can be analogous to a field in onshore Trinidad. A detailed reservoir model was built using the compositional fluid model CMG-GEM. Various scenarios were simulated to determine the optimum number of producers for primary production and the best location of the injectors for CO2 EOR. The optimum number of producers for the reservoir during primary production was found. In addition, the most favorable location of the injector to avoid early breakthrough and increase oil recovery was also determined. Many key parameters were reported from this investigation. These included OIIP, forecasted production and primary recovery. After primary production, CO2 EOR was then implemented with the use of the reservoir and fluid models and the additional recovery is reported. Other Key CO2-EOR parameters such as CO2 utilization rate and total sequestered CO2 were also quantified. Though a hypothetical reservoir was used, all associated data were defined and once an actual reservoir is known, the same technically rigid methodology can be applied. The OIIP was found to be 6.74 MMSTB for the selected reservoir. Based on an economic net present value (NPV) assessment, the optimum number of production wells for field development was found to be 3. At the end of primary production from these three wells (with 2.375 in. tubing), a total of 1.83 MMSTB were produced. This corresponded to a primary recovery factor of 27.2% over 4 years and 2 months. For CO2 EOR coupled with sequestration, these three wells were manipulated and used as 1 injector and 2 producers. CO2 EOR led to another 1.07 MMSTB of recovery for a total of 2.9 MMSTB (43.04% Recovery) for the ten year life of the project. A total of 5427 MMSCF (287 000 tons) of CO2 was sequestered in the reservoir (40.39% Storage) at an injection pressure of 1400 psi.

Economic Risk Analysis of Offshore Projects

1992 ◽  
Vol 114 (3) ◽  
pp. 165-174 ◽  
Author(s):  
E. M. Bitner-Gregersen ◽  
J. Lereim ◽  
I. Monnier ◽  
R. Skjong
Keyword(s):  
Net Present Value ◽  
Oil And Gas ◽  
Development Project ◽  
Oil Field ◽  
Economic Risk ◽  
Gas Field ◽  
Cost Overruns ◽  
Field Development ◽  
Project Assessment ◽  
Oil Field Development

A quantitative analysis of economic risk associated with large investments in offshore oil and gas field development and production is presented. The analysis is intended as a supporting tool in decision-making faced with uncertainty and risk, to study the effect of alternative decisions in an easy manner. The descriptors for the project assessment, such as the Internal Rate of Return (IRR) and Net Present Value (NPV) are applied. The study demonstrates first the impacts of early pilot production (EPP) prior to a main oil field development on the field economy of an oil field development and production installation. Furthermore, the result of cases which reflect relevant situations connected with cost overruns are presented, as well as derivation of rational decision criteria for termination/continuation of a project subjected to cost overruns. Finally, an oil field development project scheduling is demonstrated.

scholarly journals Identifying the Critical Factors in Software Development Methodology Fit

2021 ◽  
Author(s):  
◽  
Julien Lemétayer
Keyword(s):  
Software Development ◽  
Project Success ◽  
Development Project ◽  
The Other ◽  
Exploratory Research ◽  
Success Rates ◽  
Development Methodology ◽  
Project Environment ◽  
Software Development Methodology ◽  
The Impact

<p>In software development, one size does not fit all. Contingencies shape the alignment between the project and its environment, and between software development and project success. Yet the conditions favouring a particular software development methodology (e.g., waterfall or scrum) are not well understood. The current research aims to answer two questions: (1) What are the important factors in software development methodology (SDM) fit? (2) What is the role of SDM fit in project success? A review of the IT literature revealed two kinds of SDMs. On the one hand, there are traditional, plan-driven methodologies that seek compliance to a pre-established plan and existing processes. On the other hand, there are agile methodologies that seek to embrace the increasing changes and uncertainty involved in software development projects. The literature review established that there is no agreement on the contingencies associated with the use of each methodology, nor agreement on how to measure project success. Exploratory research was undertaken to identify contingencies in software development. Preliminary interviews of projects workers, using a card sort procedure, helped to identify key constructs and to generate and refine a set of measurement items. Then an international survey of software development project workers was conducted. Data analysis revealed two factors that are important in SDM fit: one is organizational culture; and the other is empowerment of the project team. The first factor encapsulates variables related to the project environment such as the level of entrepreneurship and methodology supported by top management. The second factor is related to the characteristics of the project and includes variables such as procedural empowerment and project uncertainty. No support was found for factors such as project size, criticality and the need for personnel supervision that are generally considered important contingencies. The current study also demonstrates that SDM fit is one of the predictors of project success, and affirms prior claims that one methodology does not fit all projects. The current research contributes to the SDM fit literature a contingency model that includes the impact of factors associated with the project and the project environment, on SDM fit and project success. The contingencies identified and evaluated by this research may assist practitioners to select the most appropriate methodology, and to achieve higher project success rates.</p>

scholarly journals Identifying the Critical Factors in Software Development Methodology Fit

2021 ◽  
Author(s):  
◽  
Julien Lemétayer
Keyword(s):  
Software Development ◽  
Project Success ◽  
Development Project ◽  
The Other ◽  
Exploratory Research ◽  
Success Rates ◽  
Development Methodology ◽  
Project Environment ◽  
Software Development Methodology ◽  
The Impact

<p>In software development, one size does not fit all. Contingencies shape the alignment between the project and its environment, and between software development and project success. Yet the conditions favouring a particular software development methodology (e.g., waterfall or scrum) are not well understood. The current research aims to answer two questions: (1) What are the important factors in software development methodology (SDM) fit? (2) What is the role of SDM fit in project success? A review of the IT literature revealed two kinds of SDMs. On the one hand, there are traditional, plan-driven methodologies that seek compliance to a pre-established plan and existing processes. On the other hand, there are agile methodologies that seek to embrace the increasing changes and uncertainty involved in software development projects. The literature review established that there is no agreement on the contingencies associated with the use of each methodology, nor agreement on how to measure project success. Exploratory research was undertaken to identify contingencies in software development. Preliminary interviews of projects workers, using a card sort procedure, helped to identify key constructs and to generate and refine a set of measurement items. Then an international survey of software development project workers was conducted. Data analysis revealed two factors that are important in SDM fit: one is organizational culture; and the other is empowerment of the project team. The first factor encapsulates variables related to the project environment such as the level of entrepreneurship and methodology supported by top management. The second factor is related to the characteristics of the project and includes variables such as procedural empowerment and project uncertainty. No support was found for factors such as project size, criticality and the need for personnel supervision that are generally considered important contingencies. The current study also demonstrates that SDM fit is one of the predictors of project success, and affirms prior claims that one methodology does not fit all projects. The current research contributes to the SDM fit literature a contingency model that includes the impact of factors associated with the project and the project environment, on SDM fit and project success. The contingencies identified and evaluated by this research may assist practitioners to select the most appropriate methodology, and to achieve higher project success rates.</p>

A Study on Hydrate Inhibition of Marginal Gas Field Development

2020 ◽  
Author(s):  
Hualei Yi
Keyword(s):  
Double Layer ◽  
Hydrate Formation ◽  
Economic Benefits ◽  
Development Project ◽  
Gas Production ◽  
Gas Field ◽  
Subsea Pipeline ◽  
Field Development ◽  
Development Engineering ◽  
First Time

Abstract In the marginal gas field development engineering, considering the low gas production with complex reservoir condition, it is difficult to develop independently because of the low economic efficiency. It is usually developed by relying on an existing offshore platform or facility nearby, in which hydrate inhibition is an important issue, and in order to inhibit hydrate formation in the subsea pipeline, hydrate inhibition method should be studied. Based on certain marginal gas field development project in South China Sea, which relies on nearby DPP platform, the paper studies methanol and MEG as inhibitor and application of double-layer insulated subsea pipeline. Finally by technical and economic comparisons, for the first time double-layer insulated pipeline is selected as the hydrate inhibition method to meet requirements of both relying on DPP and achieving better economic benefits, which is expected to provide reference for similar marginal gas field development.

Features and measures to improve the efficiency of development of a perspective small oil field

2020 ◽  
pp. 31-43
Author(s):  
T. K. Apasov ◽  
G. T. Apasov ◽  
E. E. Levitina ◽  
E. I. Mamchistova ◽  
N. V. Nazarova ◽  
...  
Keyword(s):  
Oil Recovery ◽  
Oil Field ◽  
Oil Fields ◽  
Transport Infrastructure ◽  
Field Analysis ◽  
Field Development ◽  
Oil Reserves ◽  
Second Stage ◽  
Recoverable Reserves ◽  
Two Stages

Despite the current political and economic situation in Russia, mining in small oil fields is important and topical issue. We have conducted a geological and field analysis of the development of one of such small oil fields from setting into operation to shut down and have identified the reasons for the low production of oil reserves and the failure to achieve the design oil recovery factor. At the same time, the field has sufficient reserves of recoverable reserves, and there is an available transport infrastructure, which proves the necessity to consider rerun it for the development. For this purpose, geological and technical actions have been developed and are being proposed for implementation to improve the efficiency of field development. These actions envisage implementation in two stages: the first with minimal costs and the second with higher costs. At the first stage, at the existing reservoir pressure, we recommend to perform forced fluid withdrawals with an increase in depression on the reservoir. At the second stage, we offer actions at a higher cost, such as hydraulic fracturing, sidetracking. As a result of the analysis, actions have been developed to increase selection from initial recoverable reserves and increase the economic efficiency when the field is rerun.

Integrated EOR Screening in a Marginal Oil Field Environment

2021 ◽  
Author(s):  
Chukwunonso Uche ◽  
Samuel Esieboma ◽  
Jennifer Uche ◽  
Ibrahim Bukar
Keyword(s):  
Enhanced Oil Recovery ◽  
Oil Recovery ◽  
Laboratory Data ◽  
Oil Field ◽  
Chemical Flooding ◽  
Implementation Challenges ◽  
Recovery Potential ◽  
Field Environment ◽  
Screening Study ◽  
The Impact

Abstract An evaluation of potential EOR processes applicable in the marginal oil field operation of the Niger Delta region is presented. Technical feasibility, process availability, oil recovery potential, and other uncertainties and risks associated with exploitation of enhanced oil recovery technique in a marginal oil field environment are being assessed. Few Enhanced oil recovery processes, namely polymer flooding, chemical flooding and microbial EOR (MEOR), are considered for possible application in this marginal oil field. The objective of the screening study is to evaluate and rank the EOR options and also select the most attractive method that will have to be further chased to a pilot test stage. Emphasis is strictly on a technical assessment of the incremental oil potential of each of the EOR methods and also identification of critical operational and logistical components of the entire process for their implementation in the offshore operating environment. Recoverable volumes associated with EOR may be significant, but key project development and implementation challenges and extra cost elements must be considered in any EOR forecast for an effective EOR process ranking. Some of these concerns (e.g. Polymer/chemical supply, facilities requirements, and the impact of EOR on reservoir performance and wellbore integrity) may be significant enough to eliminate a method from being considered further and at that point the best EOR option that requires minimal cost exposure for achieving the best recoverable shall be considered. Moreso, there is consideration of the quantity and quality of laboratory data that should support the viability of each EOR process being considered. This paper narrates the state of technical readiness for field implementation of each EOR method and identifies remaining work required to progress EOR process in this marginal oil field.

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