Putting the Reservoir to Test: An Innovative Multi-Zone Drill Stem Test Method Revealed Critical Reservoir Characteristics, Horizontal and Vertical Connectivity for Field Development Decisions and Reserve Calculations

2021 ◽  
Author(s):  
Abdullah A. Al-Fawwaz ◽  
Rashid H. Al-Obaid ◽  
Sukru Sarac ◽  
Ibrahim Kamas
Keyword(s):  
Data Analysis ◽  
Real Time ◽  
Carbonate Reservoir ◽  
Test Method ◽  
Test Sequence ◽  
Test Design ◽  
Well Test ◽  
Field Development ◽  
Drill Stem ◽  
Interference Tests

Abstract Information from dual-zone drill-stem tests (DSTs) and vertical interference tests, especially between oil and water zones, is very valuable for reservoir characterization under dynamic conditions. Despite the critical information that can be gathered for field development decisions, it is also an uncommon test type at a DST scale because of the advanced downhole test string design and operational complexity. This paper describes the objective-driven test design for a multi-layered carbonate reservoir and how the test sequence was modified in real-time to increase the value of information. An unconventional multi-zone well test with flexible on-demand control functionality was executed to resolve vital reservoir uncertainties for field development, including vertical interference between zones, individual zone characteristics and to confirm reservoir boundaries. Reservoir simulations were performed to decide the test sequence to create interference between different reservoir layers, while considering other test objectives, simultaneously. A DST string with wirelessly-activated downhole tools and flexible control options allowed to modify the test program on the fly, based on real-time data analysis and performance of each zone. One of the zones was also tested and characterized without flowing fluids to surface by making use of real-time downhole data. This complex, unorthodox well test operation was chosen to resolve multiple reservoir uncertainties in a single DST run, which would have normally required multiple different DSTs. Operations included flowing different zones individually, including acidizing operations, and the sequence was monitored and modified on the fly to maximize the value of data. Vertical interference between oil and water zones were also monitored to determine test conditions. Reservoir simulation studies helped choose the optimum test sequence to create the required interference by avoiding any disturbance in the interference data from other pressure transients during the test. During the test, downhole and surface testing data was transmitted to town in real-time and analyzed by the petro-technical team to guide the operational procedures. Downhole equipment was controlled wirelessly by acoustic commands to change the test design, depending on the data analysis. This thick carbonate formation was tested pre- and post-acid, to evaluate stimulation efficiency. Also, by testing the well at different flowrate and pressure conditions, information regarding future production well behavior was obtained. A low-pressure water zone was also tested without bringing fluids to surface, using a type of closed chamber test which was made possible by analyzing real-time downhole data from different depths. Multiple crucial objectives for field development decisions were planned and successfully obtained using an engineered DST string design. The confirmed reliability of complex DST string and wireless telemetry in difficult environment enabled well test efficiency gains to solve multiple challenging dynamic reservoir evaluation problems, simultaneously. These novel solutions bring new types of data and information to the exploration and appraisal teams to answer connectivity questions in a cost and time effective manner.

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.

Advanced Gas While Drilling GWD Comparison with Pressure Volume Temperature PVT Analysis to Obtain Information About the Reservoir Fluid Composition, a Case Study from East Kuwait Jurassic Reservoir

2021 ◽  
Author(s):  
Mohammad J. Ahsan ◽  
Shaikha Al-Turkey ◽  
Nitin M. Rane ◽  
Fatemah A. Snasiri ◽  
Ahmed Moustafa ◽  
...  
Keyword(s):  
Real Time ◽  
Oil And Gas ◽  
Compositional Analysis ◽  
Fluid Composition ◽  
Well Test ◽  
Drilling Mud ◽  
Strong Base ◽  
Field Development ◽  
Gas Drilling ◽  
Reservoir Fluid

Abstract Objectives/Scope The acquisition of mud gas data for well control and gathering of geological information is a common practice in oil and gas drilling. However, these data are scarcely used for reservoir evaluation as they are presumably considered as unreliable and non-representative of the formation content. Recent development in gas extraction from drilling mud and analyzing equipment has greatly improved the data quality. Combined with proper analysis and interpretation, these new datasets give valuable information in real-time lithological changes, hydrocarbons content, water contacts and vertical changes in fluid over a pay interval. Methods, Procedures, Process Post completion, Mud logging data have been compared with PVT results and they have shown excellent correlation on the C1-C5 composition, confirming the consistency between gas readings and reservoir fluid composition. Having such information in real time has given the oil company the opportunity to optimize its operations regarding formation evaluation, e.g downhole sampling, wireline logging or testing programs. Formation fluid is usually obtained during well tests, either by running downhole tools into the well or by collecting the fluid at surface. Therefore, its composition remains unknown until the arrival of the PVT well test results. This case intends to use mud gas information collected while drilling to predict information about the reservoir fluid composition in near real time. To achieve this goal we compared mud gas data collected while drilling with reservoir fluid compositional results. Pressure volume temperature (PVT) analysis is the process of determining the fluid behaviors and properties of oil and gas samples from existing wells. Results, Observations, Conclusions The reason any oil and gas company decides to drill a well is to turn the project into an oil-producing asset. But the value of the oil extracted from a single well is not the same as the value of the oil produced from another. The makeup of the oil, which can be determined from the compositional analysis, is an important piece of the equation that determines how profitable the play will be. The compositional analysis will determine just how much of each type of petroleum product can be produced from a single barrel of oil from that wells. Novel/Additive information Formation samples were obtained from offset wells in the Marrat Formation. These datasets gave valuable indications on fluid properties and phase behavior in the reservoir and provided strong base for reservoir engineering analysis, simulation and surface facilities design. The comparison of the gas data to PVT results gives a good match for reservoir fluid finger print, early acquisition of this data will help for decision enhancement for field development.

Integrated Subsurface to Surface Modeling to Assess Reservoir Uncertainty Quantification to A Carbonate Reservoir

2020 ◽  
Author(s):  
A. Chaterine
Keyword(s):  
Uncertainty Quantification ◽  
Gas Production ◽  
Carbonate Reservoir ◽  
Production Volume ◽  
Production Forecast ◽  
Uncertainty Range ◽  
Field Development ◽  
Production Forecasting ◽  
Production Scheme ◽  
Rock Compressibility

This study accommodates subsurface uncertainties analysis and quantifies the effects on surface production volume to propose the optimal future field development. The problem of well productivity is sometimes only viewed from the surface components themselves, where in fact the subsurface component often has a significant effect on these production figures. In order to track the relationship between surface and subsurface, a model that integrates both must be created. The methods covered integrated asset modeling, probability forecasting, uncertainty quantification, sensitivity analysis, and optimization forecast. Subsurface uncertainties examined were : reservoir closure, regional segmentation, fluid contact, and SCAL properties. As the Integrated Asset Modeling is successfully conducted and a matched model is obtained for the gas-producing carbonate reservoir, highlights of the method are the following: 1) Up to ± 75% uncertainty range of reservoir parameters yields various production forecasting scenario using BHP control with the best case obtained is 335 BSCF of gas production and 254.4 MSTB of oil production, 2) SCAL properties and pseudo-faults are the most sensitive subsurface uncertainty that gives major impact to the production scheme, 3) EOS modeling and rock compressibility modeling must be evaluated seriously as those contribute significantly to condensate production and the field’s revenue, and 4) a proposed optimum production scenario for future development of the field with 151.6 BSCF gas and 414.4 MSTB oil that yields a total NPV of 218.7 MMUSD. The approach and methods implemented has been proven to result in more accurate production forecast and reduce the project cost as the effect of uncertainty reduction.

THE EFFECT OF ONLINE VIDEO BLOG ON STUDENTS’ ACHIEVEMENT OF PASSIVE VOICE IN 4J OPERATION KENDARI

2020 ◽  
Vol 5 (2) ◽  
pp. 125
Author(s):  
Raden Alifian Setiawan ◽  
Hanna Hanna ◽  
Alberth Alberth
Keyword(s):  
Data Analysis ◽  
Real World ◽  
T Test ◽  
Test Design ◽  
Online Video ◽  
Test Results ◽  
Multiple Choice Questions ◽  
Passive Voice ◽  
Paired Sample ◽  
Post Test

The use of videos in education makes it possible to overcome practical real-world constraints and explore far greater possibilities provided by digital spaces, especially for the video uploaded in online platform such as blog. This study examines whether online video blog as media have a significant effect on students’ achievement of passive voice. It used pre-experimental (one group pre-test and post-test) design. The samples of this study were 10 students at 4J Operation. A pre-test and post-test were conducted by using multiple choice questions as the instruments. Data analysis was through paired-sample t-test. Results showed that there was an increase in mean score of pre-test (49,1) and post-test (63,5). Data from Paired Sample t-test showed that Sig. (2-tailed) was 0.000 which was smaller than .05 which means that there was significance difference in mean score after employing treatment.

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