From Reservoir Characterization to Reservoir Monitoring: An Integrated Workflow to Optimize Field Development Using Geochemical Fingerprinting Technology

2020 ◽  
Author(s):  
Faye Liu ◽  
Jiang Wu ◽  
Muqing Jin ◽  
Douglas L. Hardman ◽  
Dave Cannon
Keyword(s):  
Reservoir Characterization ◽  
Field Development ◽  
Geochemical Fingerprinting ◽  
Reservoir Monitoring

Permanent Reservoir Monitoring at Jubarte Field - 4D Results and Reservoir Characterization

2017 ◽  
Author(s):  
W.L. Ramos Filho ◽  
P. Dariva ◽  
C.C. Born ◽  
I.B. Zorzanelli ◽  
A. Goertz ◽  
...  
Keyword(s):  
Reservoir Characterization ◽  
Reservoir Monitoring ◽  
Permanent Reservoir

Validation of flow capacity and state-of-stress models in unconventional reservoirs by implementation of numerical models of diagnostic fracture injection tests

2019 ◽  
Vol 38 (6) ◽  
pp. 465-472
Author(s):  
Hernán Buijs ◽  
Jorge Ponce ◽  
Paul Veeken
Keyword(s):  
Development Strategy ◽  
Hydraulic Fracture ◽  
Reservoir Characterization ◽  
Numerical Models ◽  
Solution Space ◽  
Production Performance ◽  
Fracture Geometry ◽  
Field Development ◽  
Flow Capacity ◽  
Planar Shear

Diagnostic fracture injection tests contain critical information for reservoir characterization and hydraulic fracturing design, defining every input and output of the simulation modeling process. They help to assess the expected fracture geometry, proppant pack conductivity, formation flow capacity, and optimum hydraulic fracture design. At the same time, these data provide the necessary means to place a frac job adequately. However, interpretation challenges and inherent modeling nonuniqueness demonstrate the need for more constraints to reduce the solution space. Proprietary workflows have been applied using a 3D planar shear decoupled hydraulic fracture simulator to several vertical wells in the Vaca Muerta play in Argentina. The generated information makes it possible to build models consistent with multiple independent measurements from bottom-hole gauges, near wellbore, and far-field assessments of fracture geometry, which permit us to better understand production performance of the wells. The proposed workflow can be utilized to collapse the learning curve in a significant and meaningful way, playing a vital role in the optimization of horizontal wells and the field development strategy.

World's First Extension Pack with 7-in. Enhanced Single-Trip Multizone System: Success Case and Learning Points on the Installation and Treatment Design

2021 ◽  
Author(s):  
Sunanda Magna Bela ◽  
Abdil Adzeem B Ahmad Mahdzan ◽  
Noor Hidayah A Rashid ◽  
Zairi A Kadir ◽  
Azfar Israa Abu Bakar ◽  
...  
Keyword(s):  
Reservoir Characterization ◽  
Development Planning ◽  
Development Project ◽  
Lessons Learned ◽  
High Rate ◽  
Individual Treatment ◽  
Flow Area ◽  
Field Development ◽  
Well Completion ◽  
Gravel Pack

Abstract Gravel packing in a multilayer reservoir during an infill development project requires treating each zone individually, one after the other, based on reservoir characterization. This paper discusses the installation of an enhanced 7-in. multizone system to achieve both technical and operational efficiency, and the lessons learned that enabled placement of an optimized high-rate water pack (HRWP) in the two lower zones and an extension pack in the uppermost zone. This new approach helps make multizone cased-hole gravel-pack (CHGP) completions a more technically viable and cost-effective solution. Conventional CHGPs are limited to either stack-pack completions, which can incur high cost because of the considerable rig time required for multizone operations, or alternate-path single-trip multizone completions that treat all the target zones simultaneously, with one pumping operation. However, this method does not allow for individual treatment to suit reservoir characterization. The enhanced 7-in. multizone system can significantly reduce well completion costs and pinpoint the gravel placement technique for each zone, without pump-rate limitations caused by excessive friction in the long interval system, and without any fiuid-loss issues after installation because of the modular sliding side-door (SSD) screen design feature. A sump packer run on wireline acts as a bottom isolation packer and as a depth reference for subsequent tubing-conveyed perforating (TCP) and wellbore cleanup (WBCU) operations. All three zones were covered by 12-gauge wire-wrapped modular screens furnished with blank pipe, packer extension, and straddled by two multizone isolation packers between the zones, with a retrievable sealbore gravel-pack packer at the top. The entire assembly was run in a single trip, therefore rig time optimization was achieved. The two lower zones were treated with HRWPs, while the top zone was treated with an extension pack. During circulation testing on the lowermost zone, high pumping pressure was recorded, and after thorough observation of both pumping parameters and tool configuration, it was determined that the reduced inner diameter (ID) in the shifter might have been a causal factor, thereby restricting the flow area. This was later addressed with the implementation of a perforated pup joint placed above the MKP shifting tool. The well was completed within the planned budget and time and successfully put on sand-free production, exceeding the field development planning (FDP) target. The enhanced 7-in. multizone system enabled the project team to beat the previous worldwide track record, which was an HRWP treatment only. As a result of proper fluid selection and rigorous laboratory testing, linear gel was used to transport 3 ppa of slurry at 10 bbl/min, resulting in a world-first extension pack with a 317-lbm/ft packing factor.

Quantitative 4D Seismic Assisted History Matching Using Ensemble-Based Methods on the Vilje Field

2020 ◽  
Author(s):  
Konrad Wojnar ◽  
Jon S?trom ◽  
Tore Felix Munck ◽  
Martha Stunell ◽  
Stig Sviland-Østre ◽  
...  
Keyword(s):  
Decision Making ◽  
Seismic Data ◽  
History Matching ◽  
Reservoir Characterization ◽  
Reservoir Management ◽  
History Match ◽  
Field Development ◽  
Qualitative And Quantitative ◽  
Reservoir Models ◽  
4D Seismic

Abstract The aim of the study was to create an ensemble of equiprobable models that could be used for improving the reservoir management of the Vilje field. Qualitative and quantitative workflows were developed to systematically and efficiently screen, analyze and history match an ensemble of reservoir simulation models to production and 4D seismic data. The goal of developing the workflows is to increase the utilization of data from 4D seismic surveys for reservoir characterization. The qualitative and quantitative workflows are presented, describing their benefits and challenges. The data conditioning produced a set of history matched reservoir models which could be used in the field development decision making process. The proposed workflows allowed for identification of outlying prior and posterior models based on key features where observed data was not covered by the synthetic 4D seismic realizations. As a result, suggestions for a more robust parameterization of the ensemble were made to improve data coverage. The existing history matching workflow efficiently integrated with the quantitative 4D seismic history matching workflow allowing for the conditioning of the reservoir models to production and 4D data. Thus, the predictability of the models was improved. This paper proposes a systematic and efficient workflow using ensemble-based methods to simultaneously screen, analyze and history match production and 4D seismic data. The proposed workflow improves the usability of 4D seismic data for reservoir characterization, and in turn, for the reservoir management and the decision-making processes.

Bringing Flexibility and Automation to Well Testing Operations Through Wireless Telemetry - Case Study

2021 ◽  
Author(s):  
Elias Temer ◽  
Deiveindran Subramaniam ◽  
Yermek Kaipov ◽  
Carlos Merino ◽  
Vladimirovich Latvin ◽  
...  
Keyword(s):  
Real Time ◽  
Reservoir Characterization ◽  
Time Window ◽  
Weather Conditions ◽  
Development Planning ◽  
Testing Time ◽  
Well Testing ◽  
Well Test ◽  
Real Time Control ◽  
Field Development

Abstract Dynamic reservoir data are a key driver for operators to meet the forecasted production investments of their fields. However, many challenges during well testing, such as reduced exploration and capex budgets, complex geologic structures, and inclement weather conditions that reduce the well testing time window can prevent them from gathering critical reservoir characterization data needed to make more informed field development planning decisions. To overcome these challenges, a live, downhole reservoir testing platform enabled the most representative reservoir information in real time and connected more zones of interest in a single run for appraisal wells in the Sea of Okhotsk, Russia. This paper describes the test requirements, the prejob planning, and automated execution of wirelessly enabled operations that led to the successful completion of the well test campaign in very hostile conditions, a remote area, and restricted period. The use of a telemetry system to well testing in seven zones enabled real-time control of critical downhole equipment and acquired data at surface, which in turn was transmitted to the operator's office in town in real time. Various operation examples will be discussed to demonstrate how automated data acquisition and downhole operations control has been used to optimize operations by both the service company and the operator.

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.

Simultaneous History-Matching Approach by Use of Reservoir-Characterization and Reservoir-Simulation Studies

2016 ◽  
Vol 19 (04) ◽  
pp. 694-712 ◽  
Author(s):  
Guilherme Daniel Avansi ◽  
Célio Maschio ◽  
Denis José Schiozer
Keyword(s):  
Numerical Simulation ◽  
History Matching ◽  
Reservoir Characterization ◽  
Well Log ◽  
Log Data ◽  
Field Development ◽  
Geostatistical Methods ◽  
Well Production ◽  
Matching Process ◽  
Geological Models

Summary Reservoir characterization is the key to success in history matching and production forecasting. Thus, numerical simulation becomes a powerful tool to achieve a reliable model by quantifying the effect of uncertainties in field development and management planning, calibrating a model with history data, and forecasting field production. History matching is integrated into several areas, such as geology (geological characterization and petrophysical attributes), geophysics (4D-seismic data), statistical approaches (Bayesian theory and Markov field), and computer science (evolutionary algorithms). Although most integrated-history-matching studies use a unique objective function (OF), this is not enough. History matching by simultaneous calibrations of different OFs is necessary because all OFs must be within the acceptance range as well as maintain the consistency of generated geological models during reservoir characterization. The main goal of this work is to integrate history matching and reservoir characterization, applying a simultaneous calibration of different OFs in a history-matching procedure, and keeping the geological consistency in an adjustment approach to reliably forecast production. We also integrate virtual wells and geostatistical methods into the reservoir characterization to ensure realistic geomodels, avoiding the geological discontinuities, to match the reservoir numerical model. The proposed methodology comprises a geostatistical method to model the spatial reservoir-property distribution on the basis of the well-log data; numerical simulation; and adjusting conditional realizations (models) on the basis of geological modeling (variogram model, vertical-proportion curve, and regularized well-log data). In addition, reservoir uncertainties are included, simultaneously adjusting different OFs to evaluate the history-matching process and virtual wells to perturb geological continuities. This methodology effectively preserves the consistency of geological models during the history-matching process. We also simultaneously combine different OFs to calibrate and validate the models with well-production data. Reliable numerical and geological models are used in forecasting production under uncertainties to validate the integrated procedure.

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