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US government
Enabling Technologies for Dynamic Reservoir Evaluation and Extended Pressure Transient Testing for the Low Carbon Transition
Jackson, Richard (Schlumberger) | Gisolf, Adriaan (Schlumberger) | Dubost, Francois (Schlumberger) | Tao, Chen (Schlumberger) | Mayzenberg, Nataliya (Schlumberger) | Partouche, Ashers (Schlumberger) | Dumont, Hadrien (Schlumberger) | Yu, Hua (Schlumberger)
Abstract Oil companies are constantly trying to address uncertainties associated with reserve estimates and assessment of production, while rationalizing field development and production costs. To this capacity, formation testers are widely used to measure reservoir fluid gradients and reservoir pressure, obtain fluid samples, and assess reservoir connectivity. Dynamic data, acquired with interval pressure transient testing and well testing techniques, is used to assess reserves and productivity. However, these evaluation techniques provide dynamic data at different resolution and length scale, and with different environmental footprint, cost, and operational constraints. To help reduce development risks, an extended formation testing technique was developed in response to an industry and customer need. This technique, known as formation testing while tripping (FTWT), was introduced to the industry in 2015 with practical application around the world by a number of oil companies. The FTWT method, which was based on developments on an existing formation testing platform, integrated a number of innovations allowing pumping of large fluid volumes at higher rates, extending testing time, and circulating the produced fluids out of the well for safety and well control, without the requirement for surface flaring. These features enabled longer and safer tests, allowing deeper investigation into the reservoir compared to existing wireline transient testing techniques. Although test durations can be increased, this approach is not a replacement for a well-designed and conducted drillstem test (DST). Rather this is a method designed to bridge the information gap at the length scale between formation testing and conventional well tests. The development and introduction of a new formation testing platform with new architecture and sensor metrology has led to major improvements in capability for dynamic reservoir characterization. A new wireline formation testing technique known as deep transient testing (DTT) has been introduced, which offers significant advantages in capability and technical improvements over the previous FTWT technique. With DTT, the combination of extended flow times, increased flow volumes and rates, and new downhole pressure gauges has enabled dynamic characterization in thicker formation at higher permeability with a deeper volume of investigation than previously possible. Pressure transient testing and sampling results with application of the DTT technique is now becoming an important component in dynamic reservoir evaluation programs for addressing reservoir uncertainties and reservoir concerns during exploration and field development. The DTT technique also aligns with global sustainable development goals by enabling reductions in CO2 emissions by up to 96% percent, for the case of a 6- hour flow test at 100 B/D flow rate compared to a DST of 48 hours duration at 3000 B/D flow rate, albeit notwithstanding the difference of achievable objectives between the two techniques. Higher operational efficiency versus other wireline formation testing systems also reduces energy consumption by more than 50% - thus also significantly contributing to a reduction of emissions.
- Europe (1.00)
- Asia (1.00)
- North America > United States > Texas (0.28)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Pressure transient analysis (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Formation test analysis (e.g., wireline, LWD) (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Drillstem/well testing (1.00)
- Health, Safety, Environment & Sustainability > Sustainability/Social Responsibility > Sustainable development (1.00)
Abstract Drilling horizontal wells in complex formations is always a challenging task. The development of deep and ultra-deep azimuthal resistivity tools has largely improved the accuracy of the wellbore placement in the target zone. The enhanced imaging provided by the stochastic inversion of the azimuthal resistivity data can be applied for mapping both the internal reservoir structure and fluid contacts in the field. Major oil and gas service companies provide the operator with azimuthal resistivity tools and develop their own algorithms for resistivity data processing. Commonly services companies process azimuthal resistivity data internally. We have developed a vendor-independent stochastic inversion method that is applicable to almost any deep-azimuthal resistivity tools. This module allows operators to carry out real-time geosteering, as well as pre-job and post-job data analyses independently from the service company. This paper demonstrates the examples of the azimuthal resistivity data interpretation using synthetic data and actual data from the well offshore Norway. Calculated inversion models, based on actual data, allowed mapping of the oil-water contact and discontinuities in the reservoir that take place at the resistivity contrast boundaries. The application of this technology can increase the percentage of the horizontal well in the pay zone while letting the operator cut drilling costs through optimizing bottom hole assembly and use more advanced interpretation practices. Introduction Exhaustion of fossil energy reserves leads to the constant advancement of the drilling well targets and the increase of the number of infill wells being drilled in conventional reservoirs. The high cost and complexity of the lateral wells require thorough geosteering workflows to achieve the well target. Efficient or proactive geosteering methods require the application of the Log While Drilling (LWD) tools that could detect an approaching reservoir boundary in advance of crossing it while drilling, ultimately allowing the directional drillers to adjust the current well trajectory to stay within the well target zone. Deep and Ultra Deep Resistivity (hereinafter DAR and UDAR, respectively) LWD tools are commonly applied to achieve this aim. Modern azimuthal resistivity tools represent top-tier technological equipment that provide an abundance of multi-spacing, multi-frequency, and multi-component resistivity data and have a complex configuration. Inversion of the tool's response is the common method to interpret azimuthal resistivity data. Traditionally the tools are being provided to the operators by the service companies along with the interpretation results leaving the operators with limited opportunities to process azimuthal resistivity data. Moreover, resistivity LWD tools specifications vary significantly from vendor to vendor, and every vendor has developed their own algorithm to calculate the inversion. In order to process different kinds of azimuthal resistivity data on the operator side, we have developed the unified vendor-independent algorithm and consequently the software module that was described in detail by Sviridov et al., 2021. The goal of the current paper is to show the implementation of this algorithm on the resistivity responses from different propagation resistivity azimuthal tools on synthetic data and the real data from the Troll field located in the North Sea, Norway.
- Europe > Norway > North Sea > Northern North Sea > North Viking Graben > PL 054 > Block 31/6 > Troll Field > Sognefjord Formation (0.99)
- Europe > Norway > North Sea > Northern North Sea > North Viking Graben > PL 054 > Block 31/6 > Troll Field > Heather Formation (0.99)
- Europe > Norway > North Sea > Northern North Sea > North Viking Graben > PL 054 > Block 31/6 > Troll Field > Fensfjord Formation (0.99)
- (33 more...)
Abstract Hydraulic connectivity assessment is vital to the development of deepwater reservoirs where inaccurate characterization often results in production under-performance. Connectivity realizations are necessary for production forecasting, completion and production planning, and successful waterflood, to name a few. Seismic surveys are not always sufficient to evaluate lateral connectivity as detected faults can be transmissive or partially transmissive. Vertical connectivity represents another uncertainty where, in many cases, pressure measurements and conventional well logs are unable to detect the presence of baffles along oil columns. In moderately complex reservoirs, basic downhole fluid analysis (DFA) workflows have proven adequate to assess reservoir connectivity. However, heavily faulted reservoirs entail a comprehensive interpretation approach to address their abnormal spatial complexity. We describe a new interpretation workflow to evaluate the hydraulic connectivity of heavily compartmentalized reservoirs which comprises three pillars: areal downhole fluid analysis (ADFA), data integration, and reservoir fluid geodynamics (RFG) analysis. The concept of areal downhole fluid analysis (ADFA) is introduced to assess local connectivity leading to global, reservoir-scale connectivity. Through data integration, we analyze laboratory pressure-volume-temperature (PVT) reports, pressure surveys, well logs, and geochemistry, to establish consistency. Each data type provides insights that are pieced together to enhance consistency and reduce uncertainty. Additionally, we examine reservoir fluid geodynamics (RFG) processes that explain the reasons behind varying oil compositions and properties in different compartments, such as oil biodegradation and water washing. Our interpretation workflow provides a robust means for classifying faults into sealing, transmissive, or partially transmissive faults, as well as for detecting sub-seismic faults. The new interpretation workflow is implemented to examine a complex deepwater oil field in the Gulf of Mexico, resulting in a reliable description of hydraulic connectivity. Faults which were previously regarded as sealing faults were classified into sealing or partially transmissive faults. Sub-seismic faults were also detected as part of the interpretation. Additionally, we observed an asphaltene clustering trend that caused high oil viscosities toward the bottom of one sandstone. A correlation formula was derived and successfully used to estimate high oil viscosities where asphaltene clustering was expected.
- Europe (1.00)
- Asia (1.00)
- North America > United States > Texas (0.47)
- Geology > Structural Geology > Fault (1.00)
- Geology > Geological Subdiscipline > Geochemistry (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Sandstone (0.37)
- Geophysics > Borehole Geophysics (1.00)
- Geophysics > Seismic Surveying > Seismic Interpretation (0.54)
- South America > Colombia > N Formation (0.99)
- North America > United States > Gulf of Mexico > Central GOM > East Gulf Coast Tertiary Basin > Green Canyon > Block 826 > Mad Dog Field (0.99)
- North America > United States > Gulf of Mexico > Central GOM > East Gulf Coast Tertiary Basin > Green Canyon > Block 825 > Mad Dog Field (0.99)
- North America > United States > Gulf of Mexico > Central GOM > East Gulf Coast Tertiary Basin > Green Canyon > Block 782 > Mad Dog Field (0.99)
- Reservoir Description and Dynamics > Reservoir Characterization > Faults and fracture characterization (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Exploration, development, structural geology (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Open hole/cased hole log analysis (1.00)
- (4 more...)
Abstract Unconventional shale reservoirs have complex lithology, porosity and fluid systems where hydrocarbons are stored in both inter- and intra-particle pores. Hence, conventional log measurements and petrophysical techniques often fail to provide a consistent analysis for key petrophysical properties such as porosity and hydrocarbon saturation. Nuclear magnetic resonance (NMR) logging has gained an importance in unconventional resource evaluation, for its promise to allow in-situ differentiation of various fluid phases and their potential to flow. However, in unconventional reservoirs, pore sizes may range from only a few nanometers to a few hundred micrometers: in these small pores the NMR signal relaxes rapidly, making it challenging to measure using standard NMR acquisition modes and methodologies. This paper introduces a custom NMR log acquisition mode that is designed to measure these fast-relaxing components, to improve porosity identification and fluid typing in unconventional shale reservoirs. This is implemented through both tool improvements and novel processing techniques in the T2 and T1-T2 logging modes. Furthermore, the methodology can optionally incorporate other conventional and advanced measurements (such as, elemental spectroscopy, and multi frequency dielectric) as part of an integrated system to further constrain and compute key petrophysical properties. The methodology was applied to the Bone Spring and Wolfcamp formations of the Delaware Basin, integrating the NMR data with open hole log data, including density, porosity, and total organic content from elemental spectroscopy logs to identify organic rich zones. Integration of multifrequency dielectric measurements further increases confidence in estimating water filled porosity and hydrocarbon saturation within the reservoir. This methodology results in improved quantification of key reservoir properties such as porosity and hydrocarbon saturation. Compared to existing methodologies, benefits include increased logging speed, therefore saving rig time, improved hydrocarbon typing and quantification, and the ability to integrate with laboratory-based measurements, advanced logging suites and cuttings analysis to better identify and quantify productive zones. We present a case study applying the new NMR acquisition mode and demonstrating the improvements in quantification of the reservoir properties.
- North America > United States > Texas (1.00)
- North America > United States > New Mexico (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > North America Government > United States Government (0.49)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Shale oil (1.00)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Shale gas (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Open hole/cased hole log analysis (1.00)
Norwegian Released Wells Project: Study Design, Material Preparation, Measurements and Data Analysis
Kolbjørnsen, Odd (Lundin Energy / University of Oslo) | Hammer, Erik (Lundin Energy) | Pruno, Stefano (Stratum Reservoir) | Wellsbury, Peter (Rockwash Geodata) | Kusak, Malgorzata (The Norwegian Oil and Gas Association)
Abstract The Released Wells Initiative is a joint industry project administrated and organized by the Norwegian Oil and Gas Association and funded by the majority of companies operating on the Norwegian Continental Shelf (NCS). The project is unique on a worldwide scale, as it will analyze every drill cutting sample from every exploration and appraisal well in the Norwegian national archive. The archive contains about 700,000 samples of unwashed ditch cuttings from more than 1900 wells. Each sample is washed and dried according to a consistent automated procedure, and preserved both in a digital format, using high-resolution white light (WL) and UV (UV) photography and X Ray Fluorescence (XRF) analysis. The cleaned samples from all the wells are available for future analysis. The eighty most recently released wells were subjected to an extended suite of measurements: X-Ray Diffraction (XRD), automated mineralogy (QEMSCAN), Infrared spectroscopy (IRS) and total organic carbon measurement (TOC). We present details of the study design, sample preparation and analysis process. The extended set of observations are not selected based on the results of other measurements. The data set is therefore an independent source of information void of conditional dependencies between measurement types. We discuss the possibilities that the dataset offers and present results from analysis that have been made. In a set of repeated measurements, we find a high degree of consistency. The correlation between the two samples sets is found to be above 0.95 for XRF, XRD, QEMSCAN, IRS, and for the average photon count in white light images. For the UV images the correlation is lower, however typically these UV images have a low photon count. In a case example we show how the XRF data contribute to understanding the provenance of the Brent Group in a region of the North Sea. We show how the study design enables methods of advanced analytics, where the extended measurement set can be used to train predictive models. In our data analysis we utilize boosting threes to predict e.g., XRD mineralogy from XRF data. We report an out of sample error of 4.5%-6.9%, for quartz, total clay and carbonates. We further discuss opportunities and challenges with the dataset. The dataset provides opportunities to aid interpretation and future decision making, with impacts on drilling, completion, geological interpretation, modelling, production and future projects (including carbon capture and storage). The project is also unique in terms of openness as the complete data set will be released to the public in 2024.
- North America > United States (1.00)
- Europe > Norway > North Sea > Northern North Sea (0.46)
- Geology > Mineral > Silicate > Phyllosilicate (1.00)
- Geology > Geological Subdiscipline (1.00)
- Geology > Rock Type (0.94)
- Geophysics > Borehole Geophysics (0.95)
- Geophysics > Seismic Surveying (0.67)
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > North America Government > United States Government (0.56)
- Europe > Norway > North Sea > Northern North Sea > East Shetland Basin > Tampen Area (0.99)
- Europe > United Kingdom > North Sea > Central North Sea > Ness Formation (0.93)
- Europe > Norway > North Sea > Tarbert Formation (0.93)
- (10 more...)
- Reservoir Description and Dynamics > Reservoir Characterization > Exploration, development, structural geology (1.00)
- Data Science & Engineering Analytics > Information Management and Systems > Data mining (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Open hole/cased hole log analysis (0.95)
- Reservoir Description and Dynamics > Storage Reservoir Engineering > CO2 capture and sequestration (0.86)
- Information Technology > Artificial Intelligence > Machine Learning (1.00)
- Information Technology > Data Science > Data Mining > Big Data (0.48)
One problem for high performance yachts is to produce a light enough, strong enough structure. This is possible with modern fiberglass “composite” construction, but at substantial cost to produce the molds. Thus, composites are expensive for limited construction. However, the term “composite” means a combination of any two different materials. Prior to advent of fiberglass, “composite construction” meant a combination of wood and metal, generally wood planks and perhaps primary framing over steel, bronze or aluminum secondary framing and other heavy structure. Prince Edward’s, (later King Edward VII) famous yacht Britannia was yellow pine over steel frames and was certainly a high-performance yacht in her time. This system is now being used by a few builders of large, mainly traditional “revival” design yachts, but it is applicable to much wider range of boats and could help reduce the cost and increase the availability of limited run yacht construction (and possibly opportunities for yacht design commissions). The most important development is the ready availability of CAD/CAM/CNC design and cutting (for both metal and wood), but engineered wood, and modern coatings and adhesives, and even composite fastenings are also important enablers. The major framing structure is cut out of metal by plasma arc, water jet or laser cutters using standard metal industry techniques and equipment. The wood shell is made by strip planking, cold molding, or a combination, carvel or lap strake planking, or plywood. Planks or shell “plating” can be CNC cut as well, providing substantial reductions in labor for a oneoff or limited production boat compared to either making a mold for a fiberglass boat or for traditional wood construction. Finally, large heavy timbers are not required which not only reduces labor, but allows use of sustainable timber resources and sequesters the carbon that the tree took from the atmosphere while growing in a form that hopefully will last for some decades at least.
- Transportation > Marine (1.00)
- Materials > Metals & Mining (1.00)
- Leisure & Entertainment > Sports > Sailing (1.00)
- (6 more...)
- North America > United States > Mississippi > Ireland Field (0.89)
- Europe > Netherlands (0.89)
NASA, the European Space Agency (ESA), and the British government are dusting off a decades old idea to beam space-based solar energy to Earth from an array of orbiting satellites beaming power by laser or microwave to help reach net-zero carbon emissions by 2050, and other nations including China, Japan, and South Korea are doing the same. Once dismissed as technically impossible and far too expensive even if the technology existed, space-based solar power (SBSP) is again being assessed as a potential source of limitless clean energy as public and private sectors in space-faring nations are now seriously considering developing their own SBSP systems. The UK government's Department for Business, Energy, and Industrial Strategy commissioned a study by the UK-based Frazer-Nash Consultancy that was released in September 2021. Entitled Space Based Solar Power--De-Risking the Pathway to Net Zero, the study identified the following as drivers in renewed interest in SBSP. At the end of May, Nikolai Joseph, a policy analyst for NASA's Office of Technology, Policy, and Strategy, told the International Space Development Conference of the US National Space Society that NASA is re-evaluating the viability of SBSP after having abandoned the concept as unworkable decades ago.
- North America > United States (1.00)
- Europe > United Kingdom (1.00)
- Government > Regional Government > North America Government > United States Government (1.00)
- Energy > Renewable > Solar (1.00)
- Government > Regional Government > Europe Government > United Kingdom Government (0.92)
Abstract If properly estimated, technical revisions to disclosed proved reserves can be used to establish the reasonable certainty of both proved developed and undeveloped reserves. The trends in these technical revisions are important because they should result in overall positive revisions in EUR within a representative time period. If this criterion is not met, then the proved status of the reserves disclosed becomes questionable with the implications that this may have in depreciation, profit and loss, impairment tests and other reserves indicators where proved reserves are used. Unfortunately, in our review of the annual proved reserves revisions of developed and undeveloped proved reserves disclosed by companies to the SEC, we identified different interpretations and inconsistencies in the annual changes of proved reserves. We used data from annual reports issued between 2010 and 2020 by 141 companies, complemented by hundreds of comment letters issued by the SEC during this period, and found that companies did not apply the regulations and standards consistently, highlighting the limited effect the SEC comment letters have had in improving clarity and understanding in this important area of reserves estimation and categorization. We identified several issues which, if not carefully considered, may lead to incorrect interpretations and conclusions regarding the reliability and comparability of the disclosed proved reserves annual changes and their embedded level of certainty. The paper highlights different interpretations of key definitions and the different approaches and practices that seem to exist in companies when evaluators estimate, categorize, and disclose annual proved reserves changes due to revisions, improved recovery and extensions and discoveries, with special focus on isolating the technical revisions. We also show that the approach that some companies use to estimate the impact of changes due to changes in economic factors in the disclosed proved reserves leads to incorrect estimates and distorts the overall results or comparisons between companies. The evidence shown in the paper calls for improved and systematic official guidance if the proved reserves disclosures are to be used in a practical and useful manner. In the absence of such official guidance, this paper provides a simple project-based framework that may be used to properly analyze and extract value from the disclosed annual changes of proved reserves to improve the alignment, consistency, and proper interpretation of the disclosed proved reserves information and ensure that annual reserves changes do not end up being useless, impractical, or unreliable.
- North America > Canada > Alberta (0.28)
- North America > United States > Texas (0.28)
- Government > Regional Government > North America Government > United States Government (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- North America > United States > Texas > Fort Worth Basin > Barnett Shale Formation (0.99)
- North America > United States > Louisiana > Delhi Field (0.99)
- North America > United States > Kentucky > Illinois Basin (0.99)
- (2 more...)
Abstract JTB and SKW Field are proven fields which are hydrocarbon producing fields in Indonesia. JTB Field which is part of the Cepu Block is a proven field as well as the SKW Field which belongs to Pertamina EP Block. These two fields are 40 km apart and are currently a stranded field due to different operators. The JTB field is an early development field with CO2 characteristics > 35%, while the SKW field is a mature field with oil producers. The SKW field has been produced for more than 30 years so it is a mature field with a fairly high decline rate. Feasibility Study conducted to these project to know incremental value, especially value of engineering and carbon emission incentives from this project. After the formation of integration in the existing fields, where these two fields are under 1 Region, so that the integration of these two fields becomes possible. This integration is necessary considering that currently the JTB Field will be onstream in 2022, while on the one hand the SKW Field has started studies related to CO2 EOR. The pilot project that will be implemented is expected to be a pilot and proof of CO2 EOR which is a very new technology in the oil and gas industry in Indonesia. Carbon emissions for around that can be saved with this method become integrated value engineering that provides value creation. For implementation on pilot phase, capital expenditure about USD 75 millions with additional carbon value around USD 30 millions. This paper will use a Value engineering approach combined with environmental analysis to see the value and incremental value for these two fields. Feasibility Study of this integrated project will be used for searching another financing and get evaluated by project sanctions Deliverable for this feasibility study to calculate incremental return and amount of carbon emission value for this integrated project.
- Geology > Geological Subdiscipline > Geomechanics (0.68)
- Geology > Rock Type > Sedimentary Rock (0.46)
- Geophysics > Seismic Surveying (1.00)
- Geophysics > Borehole Geophysics (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > North America Government > United States Government (0.93)
- Asia > Indonesia > Java > East Java > Bojonegoro Regency > East Java Basin > Southwest Java Basin > Cepu Block > Jambaran Tiung Biru Field (0.99)
- Asia > Indonesia > Java > East Java > Bojonegoro Regency > East Java Basin > Cepu Block > Banyu Urip Field (0.99)
Full-Scale/Model-Scale Comparison of Podded Icebreaker’s Performance in Ice with Flexural Strength Measurement Study
Wang, Jungyong (National Research Council Canada, Ocean, Coastal and River Engineering) | Brown, Jeffrey (National Research Council Canada, Ocean, Coastal and River Engineering) | Frederking, Robert (National Research Council Canada, Ocean, Coastal and River Engineering)
Abstract This paper provides the results of model tests in ice to evaluate the performance of the USCG Mackinaw Icebreaker that was equipped with two podded propulsors and compares with the data obtained from the full-scale ice trials. The objective of this collaborative model test program between the NRC and USCG was to understand the capability and limitation of the model tests with podded vessels in ice. As a result, the model tests showed a good agreement with attainable speeds at selected power levels but an overestimation of the ice resistance by an average of 7% (from 10% to 25%). Further discussion of podded icebreaker performance including turning circle tests in ice is provided and future work is proposed. This paper also provides a discussion of two different flexural strength test methods, which are simple beam and cantilever beam tests. Introduction The number of icebreakers with podded propulsors has been increasing in recent years and many new icebreakers are planning to use the pods because of high maneuverability and additional benefits such as low noise and vibration, and various usages of the propeller wake. The first pod unit (1.3 MW) was installed in a utility vessel Seili in 1990. Since then, several ice-going tankers/ icebreakers have used single or multiple pod units, which had up to 16 MW power (Wilkman et al. 2018).
- Energy > Oil & Gas > Upstream (0.68)
- Government > Regional Government > North America Government > United States Government (0.54)
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (0.46)