Promoting healthy and sustainable cities through urban design and planning is essential to improving the urban environment and overall population well-being. The Global Healthy and Sustainable City Indicators (GHSCI) initiative is a collaborative effort that provides open-source tools to support the development of spatial indicators for urban health promotion. This study used GHSCI software to analyze spatial indicator data for the Jakarta region. The collected data were evaluated and compared with the median values of the 25 initial cities from GHSCI's first collaboration project. The research findings highlight Jakarta's comparative position among other cities within the GHSCI framework. An analysis of GHSCI reveals both strengths and weaknesses in Jakarta's efforts to achieve a healthy and sustainable urban status. Key findings include limited access to fresh food markets; high intersection density in most neighborhoods, which may serve as a potential marker for promoting walkability; and widespread access to public transportation, with the majority of residents living within proximity to bus stops. While these indicators provide valuable information, this study suggests that future refinements of GHSCI could benefit from expanded indicators that incorporate lessons from recent public health crises to better predict urban health.
This study presents an integrated approach using organic geochemistry and incident-light organic petrographic microscopy techniques to characterize kerogen type, hydrocarbon potential, thermal maturity, and the effect depositional environment has on five wells from Upper-Jurassic Kimmeridgian and Tithonian-aged source rock intervals in the Central Ridge area offshore Newfoundland, Canada. The results show that hydrocarbon potential in these organic-rich marine mudrocks is mainly dependent on depositional environment and present-day burial depth of the sediments. Oscillations and transitions between (i) rocks with dominant allochthonous organic matter (OM) (including primary/reworked vitrinite and inertinite macerals) representing high influence by continental sediments (e.g., deltaic and littoral depositional environment) and (ii) rocks with dominant autochthonous OM (fluorescing liptinites such as alginite and their degraded remains) indicating more distal, productive marine continental shelf depositional environment. The latter is of main interest to this study as it is the only rock type that has the capability to generate oil while the former has very little contribution to oil generation potential due to the abundance of hydrogen-poor organic matter. The secondary maceral, solid bitumen, occurs within the mature section in the deeper part of the basin. Measured %VRo on vitrinite macerals ranges from 0.62 to 0.82% on four of the five wells studied indicating early oil window to oil window thermal maturity due to the mixing of the organic matter types mentioned above. Integrating Fluorescent Red/Green (R/G) quotient measurements from high intensity fluorescing alginite range from 0.77 to 0.86. Conversion of these values to %VRo equivalent range 0.58–0.66% indicates that thermal maturity has not yet reached the primary oil generation window. Vitrinite reflectance equivalent derived from solid bitumen (%BRo) in the deepest buried well ranges 1.10–1.16% indicating wet gas thermal maturity.
Abstract Geological models are preferably built with very fine grids in a 3D dimensional geometry to capture reservoir complexity and heterogeneity. However, simulating such detailed models with sizes that can range to the 100’s of millions of cells is a huge challenge for current commercial CPU (Central Processing Unit) simulators as the results cannot be achieved within an acceptable time frame and simulation may last days or weeks. These long run times cause a delay in achieving a robust history matched or production forecast model as it constrains the ability to effectively characterize the uncertainty range of subsurface parameters and potential development solutions. Restricting the number of alternate scenarios in this manner diminishes the ability to arrive at solutions which may lead to loss of business opportunity and economic value. The alternatives have been used by oil and gas industry so far to reduce simulation run time, are either upscaling fine grid models to a coarser grid, consequently reducing the number of cells or increasing the number of nodes on a high-performance cluster so that simulation results can be achieved more rapidly by parallel computing using CPU based simulators. The former solution is limited by reservoir complexity and the latter by the scaling limits of the software. However, recent advances in high performance technical computing using Graphic Processing Units (GPU) has generated significant interest in the performance characteristics of a GPU-based simulator. This paper demonstrates performance of new generation of GPU based simulator as compared to CPU based simulators. A simulation run time of 9-11 hours on a 4-core CPU based simulator was reduced to 25-40 min on 1 GPU based simulator with tight bounds on results.
Abstract This paper presents three sets of new integrative production decline type curves for the analysis of horizontal well production data in order to systematically estimate reservoir flowing capacity (kh), effective horizontal wellbore length and original oil/gas in place. In addition, diagnostics of dynamic flow regimes possible for the entire flow duration from early time transient to late time boundary dominated flow gives the proposed type curves unique value in field data analysis through using different idealized flow regimes as the reference systems. Comparing to the traditional classic type curves, these three sets of type curves offer more practical implemental strategy for well performance evaluation and reservoir formation characterization, resulting in less ambiguity in the outcome of data interpretation. The effects of horizontal wellbore length and reservoir geometry on the appearances and the characteristics of these three sets of new type curves are studied and documented. A detailed curve matching process has also been comprehensively developed to achieve systematically proper matching with field data using all of the three sets of type curves synchronously. To showcase this work in field application, the production dynamics of a gas field containing two vertical non-commingled units, each being produced by a horizontal well independently, is analyzed using the three sets of new type curves. With successful estimation of the kh and the effective horizontal wellbore length, it helps geologists and geophysicists locate the "sweet spot" with more confidence and offer the potential to extend the seismic response pattern to support further exploration activity in this geology unit. The outcome of this work helped identify the existence of an untapped gas reserve in the lower unit, thus to promote the potential of infill drill to enhance ultimate gas recovery.
Abstract The International Association of Oil and Gas Producers (IOGP) is a global upstream focused forum in which member companies identify and share best practices to achieve improvements in many areas including safety. In 2017, the IOGP launched an initiative called Project Safira with the aim of eliminating fatalities. One of the work streams within this project was to refresh, simplify and reduce the number of industry Life-Saving Rules to encourage industry standardization. The development of the original IOGP eight core and ten supplemental Life-Saving Rules was based on an analysis of thousands of fatal and high potential events. An industry team of subject matter experts, HSE, and operations professionals formed as a task force. This group conducted a comprehensive analysis of the latest 10 years of fatality data and developed an updated set incorporating the latest thinking on human performance and lessons learned from member companies’ experiences in implementation. From 2008 to 2017, 376 workers lost their lives in incidents that may have been prevented by following one of the new nine IOGP Life-Saving Rules. With the benefit of having an additional seven years of data and feedback from member companies on their adoption of the previous set of Life-Saving Rules, the IOGP has streamlined the original 18 rules down to nine, while retaining the level of applicability in fatality prevention. The Life-Saving Rules are not intended to replace company HSE management systems, but are rather aimed at complementing existing organizational processes and procedures. The rules provide simple actions in the form of ‘I statements’ which can provide a final barrier that individuals have control over, and by their own actions can prevent fatalities. Having the largest database of safety performance and fatality data in the upstream oil and gas industry, the IOGP has the ability to analyze trends and build on learning from fatal incidents on an industry-wide basis.
