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Collaborating Authors
Well & Reservoir Surveillance and Monitoring
Abstract This paper describes a methodology to evaluate thermal performance in an immature giant heavy oil asset undergoing enhanced oil recovery through pattern wise steam flooding. The challenge was to predict the thermal production performance of the patterns as limited information was available on field level as the patterns were yet to show thermal decline. This methodology illustrates building and reconciling of type curve models based on the history match results of the pilot test area. These type curves are then used to predict the performance at the pattern and field level until a clear thermal decline is established. The resultant type curves are then periodically calibrated with the latest production data to ensure the validity of the methodology. This methodology is repeatable and can be adapted for use in other thermal heavy oil fields.
- Asia > India (0.29)
- Asia > Middle East > Oman (0.15)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Oil sand, oil shale, bitumen (1.00)
- Reservoir Description and Dynamics > Reservoir Simulation (1.00)
- Reservoir Description and Dynamics > Improved and Enhanced Recovery > Thermal methods (1.00)
- Production and Well Operations > Well & Reservoir Surveillance and Monitoring (1.00)
CBM Prediction: A Case Study of Field Scale Development in Bokaro Basin, India
Roy, Kalyan Kumar (Oil and Natural Gas Corporation Limited Institute of Reservoir Studies, ONGC, Ahmedabad-380005, India) | Parulkar, S N (Oil and Natural Gas Corporation Limited Institute of Reservoir Studies, ONGC, Ahmedabad-380005, India)
Abstract CBM is likely to address in a limited way the world's growing energy needs. In India the epicenter of such a process is geographically active in the east, predominantly known for conventional coal mining. Devoid of any known natural gas resource, the area though conducive for CBM production, commercial prediction needs utmost care and caution, as supply commitment is never equipped with fall back option. The geological model thus for Barakar Formation of Bokaro Field is defined with reasonable confidence for three potential CBM seams assessed through 3 vertical wells with a deliverability 10,000 m3/d for the first tested well. Proven CBM potential volumes estimated thus needs to be translated into a way forward programme of monetization firmed up through simulation based profile. A comprehensive full field dual porosity/permeability simulation model, incorporating Langmuir isotherm and GC data generated across the geographical spread is built to understand the process intricacy. Effort to history match the initial Qw with time in all CBM simulation as a depressurization event is a difficult proposition as interruption in Qw, coupled with Wp bookkeeping are often very subjective. However, permeability/volume modifiers within acceptable limits led to replicating near history of Qg and Gp. The prediction was QC'd on single well forecasting basis through other commercial software, and the profiles though identical was in substantial variation in gas breakthrough timing, the possible reasons identified as a learning for the future. Field scale development with an optimized variant of 38 vertical wells at 60 acres well spacing envisages peak Qg of 1.3 LCMD and RF being 32% after 15 years. The criticality is however well scheduling designed to cater to the industry needs of a reasonable plateau period. This paper assimilates the lessons learnt from the applications of simulation to be used for devising field scale CBM development strategy and is suggestive of the Do's and Don'ts of initial data generation and lists caution in the prediction specially the depressurization process, well spacing criteria, drilling schedule for plateau generation.
Abstract Every once in a while there comes a game changer, sometimes through serendipity and sometimes through grit and resolve. Here is a project that showcases how grit, resolve and world class management can impact an entire nation’s destiny. The discovery and subsequent development of the deepwater oil and gas fields, in the KG-D6 Block off the Bay of Bengal in the east coast of India, have important ramifications for the country’s energy security. And the discovery and development project has been executed by India’s largest corporate house, Reliance Industries Ltd (RIL). As Oil and Gas companies prepare for a surge in worldwide consumption, they must focus on Implementation of Best Practices in terms of Effective Systems and Processes to realize Operational Excellence. It translates the vision into set of business operational & measurable objectives. Today Oil and Gas Industry is having challenges like Asset Integrity, Reliability, Competency, Environmental regualtions and compliances. Inspite of these challenges, to deliver on incident free operations and production availability; oil and gas organizations are seeking industry-specific solutions. These solutions must support standards of excellence that help the organizations to achieve compliance, safety and reliability goals; improve the planning process; enable continuous improvement; and enhance organizational learning. Information is the fuel that allows leading organizations to make data-driven decisions. Effective Database Management and Information Flow are of key importance to enable organizations to continue the safe, efficient, effective and responsive operations of oil and gas business. These are the effective tools that help oil and gas organizations to achieve excellence in the areas of Asset Performance Management, Risk Management, Asset Integrity Management, Competency Management, etc. Reliance Industries Ltd. (RIL) realizes and fully acknowledges this importance of effective processes and sytems as one of the critical factors for the success of its oil and gas business. RIL has initiated the challenging initiative of implementing the best practices on systems and practices at the first ever deep water field of India – KGD6. These are strong foundation for the operataions at KGD6. Excellent data management has changed the dynamics of efficient business management during all the key stages of lifecycle of this prestigious asset – Project Development, Execution, Precommissioning, Commissioning and Steady State Operations. RIL has developed and established robust data management systems, supporting tools, systems and processes that are acknowledged as best practices across the Oil and Gas industry. Some of the best practices implemented are Bow-tie Analysis for Risk Management and development of HSE Case, Production Data Management System – Integrated with real time data from Distributed Control System, Compliance Management System through dedicated Intra-net based portal, Plant Change Management System through SAP platform, Document Management System with global search features and Competency Management System. These have not only enabled the organization to achieve flawless start-up of India’s first deep water field but also enabled to achieve Excellence-in-Excellence as recognized through various accrediations and third party International aclaimed audits. Through this paper, the authors explain the efforts taken by RIL in E&P operations to establish best industry practices and its benefits to the organization in terms of tangibles and intangibles. Some of these are mentioned as below:- ▪HSE Management System developed and well established in line with Shell Global Solutions and latest techniques of Bow-tie analysis, Tripod analysis is in place which ensures LTI Free Operations (Zero LTI). ▪Reliance Safety Observation Process (RESOP) is implemented as an effective tool for improving Behavioural Safety of own employees and contract employees. ▪Round the clock Decision Support system for Control Room Engineers through Production Simulation System (PSS), supplied by Kongsberg; Norway. PSS is integrated with Distributed Control System (DCS), which results in Flawless Operations and also effective Production Planning. ▪Production Data Management System (PDMS) – Excellent operating data management and its availability even at remote locations and corporate office on a 24×7 basis, which is a back bone for analysis and interpretation by internal experts for making corrective actions at every stage of Operations. Production Data Management System (PDMS) supplied by Halliburton is integrated with real time data from DCS through Aspentech Data Historian interface. ▪Compliance management through intra-net based portal, developed by Price Waterhouse Coopers (PWC) for effective monitoring of all regulatory compliances through a single platform, resulting in 100% compliance. ▪SAP ERP Solutions – Plant Maintenance module for effective integration, planning and mangement of resources which ensures 100% system availability. ▪Laboratory Information Management System (LIMS) supplied by LabVantage - All laboratory analsysis and results are available with trends on intranet, which enables making corrective actions immediately. ▪REIMS (Reliance Enterprise Information Management System) is established which ensures 100% availability of Documents with global search features. About 1,00,000 documents of KGD6 are presently available on REIMS. ▪Operator Training Simulator (OTS) supplied by Kongsberg, which ensures well trained and competant engineers are deployed for control room operations. ▪Process simulation packages like Aspen Plus, Hysys, PHAST, etc. are in place to enable detailed process studies for implementing plant modifications following Management of Change system through SAP platform.
- Asia > India > Andhra Pradesh > Bay of Bengal > Krishna-Godavari Basin > Block KGD6 > KG-D6 Field (0.99)
- Asia > India > Andhra Pradesh > Bay of Bengal > Krishna-Godavari Basin > Block KG-DWN-98/2 > KG-D6 Field (0.99)
- Production and Well Operations > Well & Reservoir Surveillance and Monitoring > Production data management (1.00)
- Management (1.00)
- Data Science & Engineering Analytics > Information Management and Systems > Knowledge management (1.00)
Evolution of Production Logging Technologies and Capabilities: In Quest to Know the Unknown, A Brownfield Case Study, Mumbai High, ONGC Western Offshore
Chandra, Yogesh (ONGC) | Ogra, Konark (Schlumberger) | Verma, Vibhor (Schlumberger) | Pandey, Arun (Schlumberger) | Sinha, Ravi (Schlumberger) | Kumar, Ajit (Schlumberger)
Abstract Production logging traditionally has been used to describe the flow characteristic of a well. Over the years with the advancement of the technology, for the techno economic success, deviated and horizontal wells have been drilled. Application of highly deviated and horizontal wells for field development primary recovery is now a worldwide practice. Diagnosing production problems in a near horizontal environment is a herculean task; complex flow regimes in highly deviated well aggravate complications. At the same time, with advancement in completion system design, it has become imperative to evaluate the effectiveness of the new completion design. Unfortunately traditional production logging techniques have not been successful in these conditions. One of the key issues in diagnosing production problems is detecting and distinguishing hydrocarbons in high water cut wells with water phase flowing as continuous medium at the low side and dispersed hydrocarbon phase at the high side of wellbore. Technologies like the digital entry fluid imaging tool and gas holdup optical sensor tool have proven to provide accurate results. For horizontal and highly deviated wells where recirculation, crossflow, and phase segregation further complicate the flow behavior, complete imaging of the wellbore is needed to characterize the wells. In brownfield scenario, the complications aggravate and may require real-time decision making and intensive data analysis. Some of the typical brownfield issues are scale buildup due to immense water injection for pressure support, which is required for efficient oil displacement, complex fluid flow regime, recirculation due to insufficient lift, and casing damage resulting in unwanted formation water entry. The study provides the most prolific summary and guide for case studies, success stories and lessons learned from the Mumbai High field in the last decade; evolution of the production logging tool from the most standard unit to multipoint digital entry fluid imaging, gas holdup optical sensor tools to identify and distinguish between the three fluid phases. The paradigm shifts towards the key technologies like flow scan imager to evaluate the complex borehole fluid behavior, flow regimes identification is also presented in this paper. The results derived are indispensable for future well placement campaign
- Asia > India > Maharashtra > Mumbai (0.63)
- Asia > India > Maharashtra > Arabian Sea (0.50)
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > Asia Government > India Government (0.41)
- Asia > India > Maharashtra > Arabian Sea > Bombay Offshore Basin > Mumbai High Field > L-V Formation (0.99)
- Asia > India > Maharashtra > Arabian Sea > Bombay Offshore Basin > Mumbai High Field > L-IV Formation (0.99)
- Asia > India > Maharashtra > Arabian Sea > Bombay Offshore Basin > Mumbai High Field > L-III Formation (0.99)
- (3 more...)
- Reservoir Description and Dynamics > Improved and Enhanced Recovery (1.00)
- Production and Well Operations > Well & Reservoir Surveillance and Monitoring > Production logging (1.00)
Abstract This paper describes the wide application of Production Simulator System in deep water gas field, its benefits and effectiveness. Deep water and subsea production system requires transportation of a mixture of gas/water through long subsea tiebacks from the producing well to existing production facilities. Production Simulator System is extensively utilised by Subsea operators for planning their day to day operations and predicting the systems response to current conditions and/or operator actions. The networked production software allows users to optimise and improve the system performance by monitoring wells and facilities. The optimisation process goes beyond basic operations, but extends into predicting impact of wells/manifolds start-up/shut down, subsea interventions on system performance and its deliverability. The tool also provides study on the integrity of subsea pipelines and critical flow for mid water pipelines to prevent shutdown of manifolds. Simulation studies have presented results, which were precisely similar to the real time data. While use of long subsea tie backs allows for better project economics, long flowlines causes additional backpressure on the well tending to reduce flow rates due to liquid hold up and/or backpressure increase thereby affecting ultimate recoveries. The succeeding sections in this paper will discuss how such tie-backs tend to under-utilise reservoir energy and presents alternatives for improving field life and enhance the system efficiency. Efficient monitoring of subsea gas well behavior, subsea system integrity, analyzing subsea pipelines performance and predicting problems with the software optimisation tool has resulted in significantly decreased downtime and effectively assisted in taking decisions for maintaining well production.
- Production and Well Operations > Well & Reservoir Surveillance and Monitoring > Production logging (1.00)
- Production and Well Operations > Well & Reservoir Surveillance and Monitoring > Downhole and wellsite flow metering (1.00)
- Data Science & Engineering Analytics > Information Management and Systems (1.00)
- (2 more...)
Abstract The In-situ Combustion (ISC) process has been successfully applied in the Southern part of Balol field for the last 21 years. This sector has oil of 300 cp viscosity and 15° API. The Pilot was initiated in 1990 followed by semi-commercialization in 1992 and commercialization in 1997. It has been instrumental in enhancing the oil recovery from 13% to 50%. The ISC process in the pilot stage has been modeled on the thermal simulator. At first, the 1-D Combustion tube experiment has been successfully modeled and history matched with single equation incorporating the oxidation of heavy oil. The reaction kinetics from Combustion tube model with suitable modification and the Equilibrium Constants obtained from the Equation of State (EOS) modeling of PVT experiments has been utilised to history match the ISC pilot performance. The ISC model calibrated from the history match of the actual data of the pilot shall enable in simulating the ISC process in the semi-commercial and the commercial phase. It would help in optimization of air injection rates, placement of air injectors, propagation of the combustion front, performance prediction and finally the ultimate recovery. The successful history match of the ISC process in the Pilot area in terms of water cut, liquid rates has enabled better understanding of the process. It was possible to obtain a good agreement for the propagation of the combustion front and the temperature distribution. The study has indicated that the ISC simulation on thermal simulator using single equation can be used as significant stepping stone in modeling the process in more detail using multiple equations and incorporating larger area.
- South America > Venezuela > Eastern Venezuela Basin > Hamaca Area > Bare Field (0.99)
- Asia > India > Gujarat > Cambay Basin > North Cambay Basin (0.99)
- Asia > India > Gujarat > Cambay Basin > Kalol Formation (0.99)
- Asia > India > Gujarat > Cambay Basin > Balol Field (0.99)
- Reservoir Description and Dynamics > Reservoir Simulation > History matching (1.00)
- Reservoir Description and Dynamics > Improved and Enhanced Recovery > Thermal methods (1.00)
- Reservoir Description and Dynamics > Fluid Characterization > Phase behavior and PVT measurements (1.00)
- Production and Well Operations > Well & Reservoir Surveillance and Monitoring > Production logging (1.00)
Abstract The increased application of multiphase flow in different industrial fields encouraged researchers to model the behaviors of multiphase flow in various ducts. Gasified (aerated) fluids, having 2-phases, are commonly used in drilling operations, especially for achieving underbalanced conditions. Although flow of two-phase fluids is studied in detail for pipes, not much is known for annular geometries. In this study, extensive experiments have been conducted at Middle East Technical University (METU) Multiphase Flow Loop using air-water mixtures with various in-situ flow velocities of 0-120 ft/s and 0-10 ft/s respectively for wellbore inclinations of 75°, 60°, 45° and 12.5°without inner pipe rotation. From the comparisons among data for total pressure losses, it is observed that in highly-inclined sections, by increasing the gas velocity in wellbore, the total pressure losses increase. For mid-range inclinations and nearly vertical sections, by increasing gas velocity, the total pressure losses decrease significantly, because the major part of total pressure gradient is the gravitational component. Based on experimental observations, a mechanistic model has been developed for determining the total pressure losses and volumetric distribution of each phase within the wellbore for a particular drilling condition. It has been concluded that the proposed model is reasonably accurate for estimating the frictional pressure losses when compared with the measured values. In this paper, the experimental observations and the performance of the new mechanistic model have been presented and discussed in detail.