bluuebunny/crossref_metadata_2025_split huggingface dataset:
Successful Development of the Deepest Oligocene Syn-Rift Sediment in the Malaysia-Thailand Joint Development Area: Is the Deeper Zone Our Future?
Authors: Setiawan Avidianto Suryo , Simatupang Martin Hendra , Rachmadi Arif , Apiwathanasorn Sippakorn , Moh. Said Samsul Bari 
Published: February 2023

AbstractField X, located in the offshore Malaysia-Thailand Joint Development Area (MTJDA), comprises multiple stack gas reservoirs with a combination of trap styles. This paper highlights the challenges and lessons learned in successfully developing the deepest Oligocene syn-rift sediment in the MTJDA, which was initially discovered by the one appraisal well drilled in 2010. A further comprehensive evaluation was performed to justify the deepening of development drilling in 2019 (as appraisal cum to development) and 2021-2022 (as infill wells) with promising results.The discovery of hydrocarbon resources in the deepest Oligocene syn-rift sediment at MTJDA was part of an appraisal program by deepening the development well. The two wells discovered and proved the presence of multi-stack gas sands in this deepest section (3800-4000 mTVDSS). The clastic sediment deposits in a fluvio-deltaic system. The reservoir properties of this syn-rift sediment are better than the early post-rift sediment (early Miocene). The production test confirmed the initial gas flow rate of about 15 MMscfd. A comprehensive analysis was performed to evaluate a sizeable volume before more development wells were proposed for this deepest sediment.The initial understanding of Late Oligocene syn-rift sediment was very minimal at the beginning of the project. One of the neighbouring well information suggests lacustrine delta environments based on core data. However, a fair-quality seismic amplitude shows a broader channel belt (over 3km width) which usually exists in the braided stream. In view of the two appraisals cum to development wells’ successful discovery, more than five wells were proposed to penetrate this zone as a deepening target from the existing discovered zone. The fit for purpose well designed with a monobore concept, was selected. Upon completing the development drilling with denser well spacing, it suggests the discontinuity of blocky sand presence with multiple fluid contact (stratigraphic compartmentalization), which is usually found in narrower channel reservoirs at the deltaic system rather than the braided stream. The good reservoir properties observe from the open hole log, formation tester, and production test. The success story of these wells opens future opportunities to plan more deep well to develop Oligocene sediment, which prove to be a good hydrocarbon producer.This paper updates the previous understanding of geology, such as the depositional environment, and the understanding of reservoir productivity of the Oligocene sediment in MTJDA. It also proved sizable reservoir quality with extensive lateral presence and good productivity. Hence, the company foresee a promising future from this deep reservoir to prolong its long-term development plan.
Numerical Simulation for Compaction and Subsidence During Production Period for a Large Carbonate Gas Field
Authors: Kusolsong Skaow , Adisornsupawat Kanitthorn , Vardcharragosad Pichit 
Published: February 2023

AbstractMany gas fields were discovered in carbonate build-ups located in Sarawak, Malaysia. One of the most challenges and well-known issue to operate these fields is the reservoir compaction and surface subsidence. In the new discovered field, which was recently discovered in 2019, the data related to stress magnitude and mechanical rock properties is very limited. The available cores were used to perform the essential rock mechanics laboratory test. The coupling between reservoir dynamic simulation and mechanical earth model (MEM) was selected as an approach to predict the episodic compaction and subsidence through the field life. The 1D mechanical modeling was then performed, calibrated with rock mechanics laboratory test, and used as the key input in 3D mechanical earth modeling. The coupling steps between dynamic and 3D-MEM were selected throughout the production lifetime when the pressure depletion is significant compared to the previous coupling step. Based on the literature review, the reservoir compaction and subsidence occur in this region was caused not only from the reversible elastic deformation but also from the effect of pore collapse in some classes of the limestone. This pore collapse during pore pressure depletion and increase in effective stress tends to have more impact to the subsidence than the normal elastic deformation. This behavior was also captured and incorporated using critical state criterion. The results of the coupling will strongly have the impact on how the platform will be designed to account for potential subsidence throughout 20 years of production. Due to the limitation of input parameters in the 3D-MEM, the sensitivity analysis was performed to assess the impact of each mechanical properties on the magnitude of the reservoir compaction and subsidence. The use of ready coupled 3D-MEM can also be further extended to other applications such as wellbore integrity, wellbore stability analysis, and mud weight optimization at any given period of time. Moreover, the impact of the compaction and subsidence in this study could leads to better planning in data acquisition such as rock mechanics data, laboratory test, and logging acquisition program to narrow down the uncertainty of the subsidence analysis and other geomechanical applications.
Unlocking the Potential of Unlabeled Data in Building Deep Learning Model for Dynamometer Cards Classification by Using Self-Supervised Learning
Authors: Wibawa Ramdhan , Rosyadi Rosyadi , Nancy Maulirany , Irfani Hasya Fulki Raden 
Published: February 2023

AbstractDynamometer card is one of the vital surveillances for Sucker Rod Pump (SRP) performance monitoring in Duri field. Even though the field produces a massive number of cards, they come with no label or interpretation about the pump conditions based on the card shape. Self-supervised learning (SSL) consists of a pretext task that trains feature extractors by using unlabeled data as opposed to supervised learning, that requires a lot of effort in labeling data which is time consuming and costly. This paper evaluates the performance of a feature extractor, Alexnet, that is trained by using several pretext task techniques. This study used around 660,000 unlabeled cards while a small amount of labeled data was used for evaluation purposes using linear evaluation protocol. The result showed that the trained Alexnet using Pretext-Invariant Representation Learning (PIRL) with jigsaw has better performance by 6% compared to the pre-trained ImageNet model. Further fine-tuning process by using labeled data could achieve 93% accuracy. The model was also tested using fresh data and the result was compared to the expert's interpretation. This approach can potentially add more types of rod pump problems to detect in the Duri field with considerable precision. In addition, the new approach could improve the current method of detecting more SRP with valve leaking problems.
Taking Petrophysics to New Horizons – Far Field Saturation and Lithology in Clastic Reservoirs
Authors: Hermawan Manuaba Ida Bagus Gede , Ghanim Rayan Adil , Bikchandaev Eduard , Taher Ahmed 
Published: February 2023

AbstractConventional logging-while-drilling tools acquire measurements close to the wellbore. Recent development of deep and ultra-deep resistivity technology has enabled measurements more than 100 ft from the wellbore. Far-field petrophysics in simple carbonate lithology is possible since saturation is dependent on resistivity and porosity. Hence, combining deep and ultra-deep resistivity measurements with data from offset wells can provide reasonable saturation mapping. However, in clastics the evaluation is more complicated since resistivity is more dependent on lithology.In most cases, the main challenge in carbonates is permeability identification. Far-field carbonate petrophysics can be derived from mapped resistivity utilizing deep or ultra-deep resistivity and offset logs. Evaluation of far-field petrophysics away from the wellbore in clastics is more complicated as it requires lithology identification to be incorporated into the petrophysical model. A workflow has been developed integrating near-wellbore measurements with ultra-deep resistivity and anisotropy derived from 3D inversion. The workflow provides a qualitative indication of the lithology, allowing saturation in porous sand to be derived based on inverted resistivity.An innovative workflow has been developed based on the available data and combining multiple sources of data from near wellbore, offset logs to inverted resistivity data. 3D inversion plays a critical role in this workflow as it provides a lithology indication far away from the wellbore, differentiating between shale and sand. The identification of shale members at a distance also provides critical information for models of reservoir connectivity and potential barriers to water influx. The combination of far-field petrophysics with lithology gives better evaluation on a reservoir scale for critical decisions in terms of completion and reservoir performance.The new workflow has been successfully tested on several wells and different reservoirs. The workflow has been used for far field petrophysics and saturation mapping based on real-time logging-while-drilling (LWD) data and offset data analysis combining shallow and deep measurements with the 3D inversion from ultra-deep resistivity. There are several benefits from this innovative workflow, including optimizing well placement, improving understanding of fluid distribution, and optimizing completions design and reservoir management strategies.
Resolving Uncertainty in Oil Quality and Extension of Field Producible Area Using Latest LWD NMR Technology
Authors: Al-Fawwaz Abdullah A. , Usman Anes Y. , Najem Mohammad M. , Aboudi Abdulrahman , Al-Otaibi Fahad , Van Steene Marie , Dolan James 
Published: February 2023

AbstractThis paper describes how the uncertainty in oil quality in an offshore carbonate reservoir was resolved using the latest slim logging-while-drilling (LWD) nuclear magnetic resonance (NMR) tool. This tool was included in the bottomhole assembly (BHA) during drilling of the sidetrack well with the objective of confirming the presence of immovable heavy-oil/tar mat below the light/heavy-oil contact (LHOC). However, the tool showed that the reality was different from the expectations as movable/light hydrocarbon was confirmed below LHOC thereby leading to an extension of the field producible area.The NMR interpretation methodology followed two scenarios based on an offset well with a rich NMR dataset. In the first scenario, because of the absence of porosity deficit and low apparent bound fluid volume, no heavy oil was identified, and the tool provided permeability and irreducible water saturation. In the second scenario, heavy oil was identified primarily from the presence of high apparent bound fluid and secondarily by a porosity deficit, and oil viscosity was computed.The high-angle well intersected the same carbonate reservoir layer multiple times. The NMR measurement showed that Zones A–1, A–3, and B contained light oil, while the expectation for Zone B was to contain a heavy oil layer below the LHOC. The NMR identified heavier oil in each crossing of Zone A–2. An oil viscosity gradient was observed on both crossings of the reservoir layers. The reservoir was otherwise at irreducible water saturation in the subsequent interceptions, and the heavy oil or tar were not identified again. All the observations from the tool were supported by related observations from the mud logging gases. The first application of this service in this field was a success. The NMR provided unique fluid typing information, confirming that most reservoir sections contained light oil and quantified the heavy oil viscosity variations along the reservoir layer, which could not be quantified from the density, neutron, or resistivity measurements.Finally, the NMR measurement showed that the reality of heavy oil distribution in this part of the reservoir was quite different from what was expected (i.e. the presence of immobile heavy oil below the LHOC) based on the reservoir model, enabling the prospect of light oil production from this part of the reservoir.
Research and Practice of Steam Huff and Puff Depressurization and Increase Injection Volume Technology for the First Offshore Super Heavy Oil Reservoir in China
Authors: Wang Hongyu , Wang Qiuxia , Han Xiaodong , Zhang Hongwen , Liu Hao , Wang Cheng , Zhang Hua , Wang Zhiyuan , Dou Peng 
Published: February 2023

AbstractThe surface crude oil viscosity of the first ultra-heavy oil field in Bohai Oilfield is more than 50,00mpa·s, which is unable to be developed under the condition of original formation temperature and requires steam stimulation. In the first period of steam huff and puff well, due to sufficient formation energy, steam injection pressure is high in the process of steam injection. The measures to reduce the steam injection speed are mostly adopted in the field, but it will lead to the problem of large wellbore heat loss and affect the steam stimulation heat injection effect. In this paper, based on the oil characteristics of the first ultra-heavy oil field in Bohai Oilfield, the evaluation of oil soluble surfactant was carried out, and the experimental study of pre-injection of oil soluble surfactant to reduce steam injection pressure was carried out. It has been successfully applied in the development of the first ultra-heavy oil in Bohai oilfield. The results show that the oil soluble surfactant with asphaltene dispersibility has better temperature resistance and viscosity reduction effect, and the viscosity reduction effect is more than 95% before and after aging. Laboratory experiments show that the oil soluble surfactant can reduce the steam displacement resistance of the displacement front and the affected area. When the injection amount of oil soluble surfactant is 0.2PV, the maximum steam injection pressure can be reduced by 22.9% and the steady steam injection pressure by 10.8%. The design treatment radius of oil soluble surfactant is 0.15m, and the field test shows that the steam injection pressure decreases by 1.1MPa during steam injection.After adopting the depressurization and increase injection volume technology, the field injection pressure is effectively reduced, the steam injection effect of ultra-heavy oil is guaranteed, and the technical guarantee for the subsequent development, promotion and application of ultra-heavy oil is provided.
Increasing Run Life by Using Multiple Preventive Downhole Pump (MPDT) to Overcome Gas Interference and Sand Problem on Sucker Rod Pump Well
Authors: Suryantoro Rahma Wisnu , Oktoviyanto Yusuf , Dewanata Dionisius , Arif Luqman , Akbar Despredi 
Published: February 2023

AbstractRantau is a mature oil field located in Aceh, Indonesia, which has been producing oil since 1928 and reached the peak production in 1970s. The reservoir in Rantau field is already depleted so it needs artificial lift to produce the oil. About 71% of artificial used in Rantau are sucker rod pump (SRP), 26% are electric submersible pump (ESP), and others remaining are gas lift. To maintain production with a high decline rate efficiently gets more challenging with the downhole problem, especially gas interference dan sand problem.In 2020, 78% of well services came from artificial lift wells with sucker rod pumps. The data said that sand problem with gas interference became dominant causes in 74% of the cases. To solve those issues with the limitation of cost and maximizing the effect, modification of tubing pump accessories was chosen. Multiple Preventive Downhole Pump (MPDT) is a modified tubing pump accessory that has seven stages to minimize sand production and separate the associate gas while the fluid was pumping into the surface.The sand separation was effective enough to prevent a huge amount of sand and gas from the reservoir infiltrating the pump assembly, so the sand could not produce to the surface or blocking the standing or traveling valve and gas pound could not occur. The four wells installed with MPDT could exceed their previous run life more than five times. This brings impact on the less well service activity in those wells and for Rantau field in general. During the observation, the fluid sample taken from the wellhead showed no sand to a small amount of sand produced, as the wells produced a small amount to no sand at all we could optimize its parameter to achieve more oil, while when the well produced a huge amount of sand, its parameter could not be optimized or increased which could lead to more sand produced to the surface. In conclusion, well that installed with MPDT become more efficient contributed by longer run life which led to less well service work and increased oil production where its parameter could be optimized.MPDT could prevent reservoir sand getting into the tubing pump, as well as the gas. It is a practical solution for mature oil fields that encounter sand problems as a common challenge in producing oil.
Apply Cost Effective Multiple Cementing Technologies to Sidetrack in Air Drilling Environment in Chiya Khere Field
Authors: Hasan Hawraz , Ibrahim Krewa , Majeed Ali , Shafqat Ali , Abdulfattah Suwar , Ibrahim Mohammed , Qader Rebeen 
Published: February 2023

AbstractChiya Khere field development plan is to drill a lateral hole from existing pilot holes. While in the drilling phase, severe losses were hindering the drilling plans due to lack of effective solutions to sidetrack in air drilling environment. Historically, losses circulation pills were never effective to cure the losses in highly fractured zones, the drilled wells in this field were abandoned using mechanical barriers (Bridge plugs) to facilitate the lateral plan, which was increasing the field development time and cost. Also, due to difficulties to obtain open-hole mechanical bridge plugs the well project duration was extended significantly, furthermore, isolating the loss zone using mechanical tools is the least preferred primarily due to availability and then setting failures in the big hole. In this paper, a newer approach will be presented to demonstrate the specialized technique to cure total losses which resulted in a significant reduction in the operational cost to drill these laterals in Chiya Khere field without changing the casing designs or postponing the project due to no viable solution and explains detailed techniques to overcome the challenges. Some techniques to combat severe losses are pumping loss circulation pills, drilling under balance, and pumping cement plugs. A new and unique loss control strategy was introduced in one of the recently drilled well in this field, in which two pills of solid free spacer separated by a fiber carrier fluid were pumped for instant bridging and viscosifying at the downhole were injected into the losses zone to create a temporary lock-up prior to pumping a rapid gelled cement plug for permanent isolation, once the losses been controlled a firm base cement plug was placed to spot a high compressive strength cement plug (kickoff cement plug), Applied proposed techniques led to having successful results in which rapid gelled cement headed by losses circulation material (LCM) solution combination cured the losses and successfully isolated the bottom of the hole which facilitated to placement a basement plug then kick off cement plug, and tag at the designed top of cement (TOC) to drill the lateral to the new planned trajectory.
Data-Driven Performance Analysis for Candidate Recognition: A Case Study in a Giant Heterogeneous Carbonate Reservoir
Authors: Sun Liang , Wu Bohong , Gao Yan , Li Yong , Jiao Yuwei , Wei Chenji , Shi Shuzhe 
Published: February 2023

AbstractIn the whole lifecycle of reservoir development, periodic intervention in wells is the daily work of reservoir management, which is essential to production maintenance and workover activity. The identification of actionable plan at well-by-well level is time consuming and inefficient, especially for reservoirs with a considerable amount of wells. Over-reliance on engineer experience also increase uncertainties over reliable plan. The workflow for candidate screening provides a systematic and efficient approach to dealing with this issue.Prior to commencing the process, reservoir static model and dynamic model were updated to meet recent reservoir performance. The first step was to identify potential wells in two ways, including the typical diagram indicating the relationship between production performance and reservoir properties, and the modified heterogeneity index method introduced by Del Castillo et al. After completing candidate recognition, diagnostic analysis was conducted to determine root causes through dynamic analysis of injection/production performance at well/pattern level. Finally, comprehensive evaluation and forecast for workover activities were carried out in terms of technical and economic aspects, which will facilitate appropriate decision making.This workflow has successfully been applied to a giant heterogeneous carbonate reservoir with gas cap. The identified candidates can be categorized into four types. The whole/partial gas cusping wells with a sharp/gradual increasing trend in gas-oil ratio (GOR) are influenced by gas cap. The gas channeling wells with uneven sweep efficiency are attributed to the injected gas overriding in heterogeneous reservoir. The water cusping wells with medium water cut are influenced by bottom aquifer. Accordingly, an integrated optimization plan is proposed to mitigate the outlined risks. The recompletion strategy with Autonomous Inflow Control Device (AICD) and sliding sleeves is recommended for gas/water cusping wells, and results are phenomenal in terms of segmented isolation of high GOR/water cut intervals and delaying gas/water breakthrough. The converting from gas injection to tapered water-alternating-gas (TWAG) through increasing the ratio of water-to-gas in a step wise process has been implemented for gas channeling wells, and an improved conformance is observed. The TWAG project appears to be promising because of high gas/water utilization efficiency and reduced gas cost.This methodological approach provides a generic workflow for conducting an integrated analysis of workover candidates screening and plan making. Reservoir performance will be monitored and maintained in order to ensure efficient reservoir management practice.
Capacidad de absorción del conocimiento y sus factores de impacto en la perspectiva empresarial colombiana
Authors: Garcia Valenzuela Victor Manuel , Jacobo Hernandez Carlos Armando , Ochoa Jiménez Sergio 
Published: February 2023

La capacidad dinámica de absorción de conocimiento es una herramienta clave para la gestión de conocimiento definida como el proceso de adquirir, asimilar, transferir y explotar conocimiento externo con la finalidad de generar mayor valor agregado mediante ventajas competitivas. Para verificar lo anterior, se aplicó un cuestionario de 16 ítems a 45 empresas colombianas y a través del método análisis de varianza de un factor, se analizó la diferencia de medias entre las dimensiones de la capacidad dinámica de absorción, en función a los factores: tamaño, sector, antigüedad y número de empleados de las empresas. Los resultados muestran que con un nivel de confianza del 95% se puede determinar que el tamaño y antigüedad de las empresas presentan variaciones significativas en las dimensiones de la capacidad de absorción en la perspectiva de los empresarios de Colombia del sector servicio. Los hallazgos son de gran utilidad para los empresarios que les permitan tomar mejores decisiones gerenciales, para el gobierno en la generación de programas sociales enfocados a incentivar el aprovechamiento del conocimiento externo absorbido por las empresas y a la comunidad científica con el estudio de la capacidad dinámica de absorción del conocimiento en las empresas.