bluuebunny/crossref_metadata_2025_split huggingface dataset:
Best Practices Applied in Drill Stem Testing of HPHT Wells With the Presence of Very High H2S and Super Saturated Saline Water in the State of Kuwait
Authors: Al-Ajmi Bader , Al-Ateeq Abdullah , Kumar Munna , Abdullah Abdulkareem Mohammad Ibrahim 
Published: October 2023

Objective/Scope
The objective of this paper is to present the best practices applied in drill stem testing of wells with harsh environment due to presence of high sour fluid. For the first time in State of Kuwait, five exploratory wells were tested with several challenges namely high pressure, high H2S (~ 40%), super saturated saline water leading to salt plugging both at surface and downhole, flaring / safe disposal of produced well fluid, intervention using coil tubing for activation and acid stimulation, rates measurement, production logging and bottom hole sampling etc.,. Best practices of well test along-with fit for purpose equipment were used. This resulted in successful data collection of the subject wells without any damage to personnel and environment.

Method, Procedure, Process
Five deep Jurassic wells were drilled with heavy mud 18.9 - 20.4 ppg to 11,107 ft. - 15,550 ft. targeting new formations with many anticipated challenges like high pressure 10,900 - 14,500 psi, high temperature 220 - 260 degree F, and ultra-sour reservoir fluid with H2S concentration up to 40%, super saturated saline water with water cut up-to 100%.
The operational challenges were suitably addressed by means of meticulous planning, application of additional equipment and alternate approach. Continuous dozing of H2S inhibitor & scavenger protected surface test lines & equipment. Flow measurement is accomplished by using multiphase flow meter in addition to test separator to handle very high H2S concentration. To achieve uninterrupted flow and to avoid/overcome salt plugging at surface, continuous brackish water pumping arrangement was installed in the upstream line of choke manifold. For continuous uninterrupted produced fluid disposal & flaring, two flare-pits with green burners are made to avoid well closing due to unfavorable wind direction. Bottom-hole samplers were deployed on DST test string facilitating to capture representative reservoir hydrocarbon samples as and when required. During coil tubing intervention for well activation & downhole salt bridges clearing, continuous H2S inhibitor pumping was done. All safety precautions was adhered as per company norms for H2S monitoring and handling. Wireline production logs remained a challenge in these well wells due to harsh environment.

Results, Observations, Conclusions
Setting up suitable measures helped in executing successful well tests in new formations without any damage to personnel and environment.

Novel/Additive Information
For the first time in State of Kuwait, in five deep HPHT wells, new formations with many challenges were tested successfully. This resulted in a new level of confidence to execute testing operations in extremely harsh environment and encouraged in Exploration activities.
Improving Velocity Modeling with Surface Drilling Data Using Machine Learning
Authors: Gong B. , Hossain A. , Sanclemente K. A. , Alli O. G. , Harvey B. , Wang K. 
Published: October 2023

Abstract
Subsurface velocity models play a vital role in the conversion of seismic data from travel time to horizon depth. However, in practice, the calibration of velocity models can be challenging due to the limited availability of sonic logs. As a result, depth uncertainties may be introduced to the seismic images, potentially impacting the accuracy of geological interpretation. In this paper, we leveraged the known correlations between drilling parameters (e.g., rate of penetration, weight on bit and torque) and mechanical properties of formation rocks to construct a machine-learning model that estimates sonic velocity. Trained with well data from an unconventional field, the model successfully generated predictions that closely tracked actual sonic logs in blind test wells.
The workflow consists of data preparation, exploratory data analysis (EDA), modeling and testing, and interpretation. The steps of data preparation and EDA were both conducted with the guidance of domain knowledge to ensure any preprocessing and interpretation are contextually reasonable. In the modeling phase, a two-stage Random Forest regression model was trained and fine-tuned, in which the second-stage model learns from the residuals from the first-stage predictions. Overall, the model demonstrated effectiveness by capturing the trend of sonic velocity with respect to depth across the majority of intervals. We observed that the prediction errors are overall symmetric around zero but varied with depth, which was likely caused by data quality issues in shallower intervals. Among the input features, true vertical depth made the dominant contributions to the prediction, likely due to the low dips and low lateral variability of the local geology. Other key predictors included revolutions per minute, hook load and weight on bit.
By incorporating estimated sonic velocity profiles, the resolution of existing velocity models can be enhanced both vertically and spatially, while avoiding additional costs for data acquisition. In addition, the capability of estimating velocity during drilling offers new opportunities to inform real-time decisions in operations, as updates could potentially be made to the horizons ahead of the bit as new drilling data stream in.
Improving Production Enhancement and Idle Well Reactivation (PE/IWR) Success Rate at Country Level in Malaysia Via PE/IWR Qualifier Matrix Approach
Authors: Bakar Hasmizah , Khairul Anuar Khairina , Mokhtar M Khaidir , Idris Khairul Nizam , Khalid Ruzanna , Abu Bakar Mohamad , Masoudi Rahim 
Published: October 2023

Abstract
Production enhancement and idle well reactivation (PE/IWR) activities have been proven to be more economically attractive and quick win enabler to revitalize Malaysia production landscape as compared to other workstreams such as deferment management, well integrity healthiness, new hydrocarbon delivery and prudent reservoir management plan. A magnitude of approximately 1000 reservoirs mapped to 100+ oil and gas assets across three land masses is roughly the hydrocarbon capacity in Malaysia. Each year thousands of rig and rigless interventions are carried out across 3000 wells completed in shallow and deep water assets that are operated more than 15 operators.
As regulator and host authority for all hydrocarbon resources in Malaysia, it is critical for Malaysia Petroleum Management (MPM) to scrutiny PE/IWR proposals submission by operators not only to maximize production from active strings and improve the idle string management but also to arrest further value leakages. This paper will emphasize the transparent methodology established by MPM team to rank PE/IWR activities which required regulatory approval for execution based on risk value, chance of success and doability on how quickly to realize gain. The prioritization method through PE/IWR Matrix Qualifier ranking starts as early at the stage of yearly work program budget planning and followed by multi-disciplinary technical commercial value assurance committee for final approval. The level of attractiveness of PE/IWR opportunities will correspond to its rating. Those operators with low qualifier rating activities are required to refine the jobs value attractiveness in the event the operators insist to pursue the executions are also outlined in this paper. All prioritized (medium and high qualifier rating), approved and planned opportunities are then turned into execution pipeline and properly tracked into a systematic methodology for post job analysis, evaluating the success of the jobs and recording the lesson learned for improved future jobs quality.
Value proposition of PE/IWR Matrix Qualifier in MPM more than a job prioritization tool comes through intensification of ranking efforts and standardization process for PE/IWR budget approval of overall Malaysia hydrocarbon assets to realize business production target. This approach is one of the factors that has significantly improved 2022 PE/IWR gain by 22% against last year actual gain, increased the activities success rate from 52% to 65% with substantial USD16million cost avoidance for unnecessary spending. The authors would also like to share their experience as devoted Shapers and Enablers to safeguard Malaysia production target that may inspire other petroleum authorities in transforming the ambition(s) into action.
Maximizing Recovery in Deep-Water Gulf of Mexico Assets. Surveillance in Complex Subsalt Reservoirs
Authors: Cedillo G. , Zett A. , Han X. , Peraser V. , Gelvez C. , Saidian M. , Ortego A. , Mammadli R. 
Published: October 2023

Abstract
Deep water surveillance in the Gulf of Mexico (GoM) is a very challenging and capital extensive commitment for operators. Maximizing production by understanding reservoir storage capacity and deliverability is a complex task as multiple realizations could be drawn using permanent gauges and production rates, especially when the well is not performing as expected.
Gathering petrophysical surveillance that supports well work and, or well remediation in wet tree production systems is complex and challenged by well access, environment conditions (high flow rates, high pressure) and availability of sensors that provide representative measurements in such conditions. To maximize the outcome, efficient combinations of sensors are designed to provide reliable reservoir surveillance and well integrity data. The data is holistically combined to provide a quick turnaround for results that feed into decisions trees, that reduce rig time and minimize the production deferrals.
In this paper we present the results of a novel sand detection instrument suitable for deep-water environments. We also present holdup instruments combined from different vendors in the same wells to address the high flow rate quantification limitations due to friction and flow regime changes. We will share several examples of time-lapse cased hole fluid saturations in complex well completions. We will share a workflow that proved successful over the recent downturn in the industry. This workflow addresses the uncertainty in nuclear attributes by using flow diagnostic sensor integration as constraints.
Currently, we are the only operator in GoM running active surveillance in deep water wet trees &gt;25k ft. This paper shares the novel techniques and instruments used to evaluate different types of surveillance and how they contributed to maximize recovery by measuring key parameters critical for reservoir modelling, such as fractional flow, time-lapse residual saturations, or flow rate splits per reservoir.
Challenging the industry status quo enables us to change the game in flow diagnostics determination in our high value wells. By identifying new sensor combinations that complement the existing technology offer with novel workflows and the inventive approach to progress such solutions, we are happy to share our success and lessons learned.
Impact of Salinity and Temperature on Wormhole Generation Due to CO2 Sequestration
Authors: Aldhafeeri Abdullah , Mirzayev Elvin , Aljawad Murtada Saleh , Al-Ramadan Mustafa , Ibrahim Ahmed Farid , Al-Yousef Zuhair , Almajid Muhammad M. , Al-Ramadhan Ammar Mohamad , Al-Yaseri Ahmed 
Published: October 2023

Abstract
Deep saline aquifers are good candidates for carbon dioxide (CO2) sequestration. The reaction between the CO2 gas and the saline water aquifer creates carbonic acid (live brine) that reacst with the formation rock to generate wormholes. As a result, the rock mechanical properties will be altered. The goal of this study is to understand the impact of salinity and temperature on creating wormholes due to live brine injection.
Limestone core samples (1.5 × 3 inches) with a permeability of 2 – 4 mD and 15-17% porosity values were selected to perform the study. Coreflooding experiments were performed, after which the samples were scanned to observe the wormhole generation and the change in the pore structure. Carbon dioxide was mixed at 2,000 psi with a ratio of 30% CO2 to 70% brine to formulate a live brine. The live brine was injected into the rock samples at different temperatures (35 °C, 60 °C, 85 °C). Also, CO2 was mixed in the brine width with different salts concentrations (40,000 ppm, 120,000 ppm, 200,000 ppm), which were then injected into the rock samples to test the impact of salinity. The mechanical properties of the samples before and after wormhole generation were studied using impulse hammer and acoustics.
The injection of the live brine generated wormholes in all low-permeability rock samples. Due to the wormhole's generation, the rock samples' porosity and permeability increased significantly. The time to generate the wormholes has a positive relationship with the salinity and temperature. For instance, it took around 5.5 hrs of live brine injection at 1 cc/min to create a wormhole at 35 °C, while it took more than 10 hrs at 85 °C. Similarly, it took only 3 hrs to generate womrhole in the low salinity samples while double the time for the high salinity ones.
This research's novelty stems from its application to CO2 sequestration by investigating the salinity and temperature of saline aquifers. These two parameters are significant ones that distinguish aquifers. This is the first study to understand the impact of salinity and temperature on wormhole generation due to CO2 sequestration.
Impact of Well Interference on Transient Pressure Behavior During Underground Gas Storage: A Comparative Study
Authors: Chu Hongyang , Zhang Jingxuan , Li Jiawei , Zhu Weiyao , Ma Tianbi , Gao Yubao , Lee W. John 
Published: October 2023

Abstract
Underground natural gas storage (UGS) is key to achieving carbon neutrality and it is also a potential solution to the seasonal imbalance between gas supply and demand. To store or withdraw a large amount of natural gas within a specified time, wells in UGS projects often need to have high continuous injection and withdrawal capacities. High injection and withdrawal rates lead to uneven pressure distributions in UGS and substantial well interference. This paper proposes an analytical model to investigate the impact of well interference on transient pressure behavior in UGS wells. We used Laplace transforms and the Stehfest numerical inversion algorithm to obtain an analytical model of the pressure response of a vertical well in a UGS project. We used the superposition principle to model well interference effects, and we used a commercial numerical simulator to validate analytical solutions for different cases. Results show that the pressure behavior during interference depends mainly on the operational status of adjacent wells. When an adjacent well is withdrawing gas, interference causes the pressure derivative to first rise and then flatten later. When gas is injected into the adjacent well, the pressure derivative curve drops continuously and is similar to the shape for a well near a constant pressure boundary. The types of adjacent wells affect the rate of rise of the pressure derivative curve at later times. Interference with a target well is more likely when we inject into or produce gas from a vertical well than from a horizontal well. The application of our methodology is illustrated for the Hutubi UGS. Available data from nine cycles of injection and withdrawal in this UGS project indicate that the cumulative gas injection volume and the gas withdrawal volume were 155.43 × 108 m3 and 130.81 × 108 m3. The final gas storage volume eventually reached 93.5% of the designed UGS capacity.
An Efficient Approach for Automatic Parameter Inversion Based on Deep Learning
Authors: Li Dexuan , Chen Zhiming , Sepehrnoori Kamy , Sun Xiaoguang 
Published: October 2023

Abstract
Parameter evaluations are the first and primary tasks to understand the natural gas hydrate reservoirs. However, there still lacks some effective means for parameter evaluations in hydrate reservoirs. To improve this situation, this paper tries to combine the well testing with deep learning (DL) method for solving parameter inversion problems of natural gas hydrate wells. First, a radially-composite well testing model with dynamic interface is developed to represent the hydrate dissociation driven by depressurization. Then, by Laplace transform, the wellbore pressure is solved and adopted to train a one-dimensional convolutional neural network (1D CNN) and the optimal convolutional neural network (CNN) is obtained by minimizing mean square error. In the CNN, the wellbore pressure is used as input of the network after nondimensionalization, and the interpreted parameters are permeability, wellbore storage coefficient, skin factor and dissociation factor. Finally, the well testing and DL method is verified and applied in a field case.
Results show that the sensitivity of the parameter on pressure transient behavior will affect the accuracy of parameter inversion. The 1D CNN is tested with synthetic data, which shows great practicality and high accuracy of curve matching. During the field application, when compared with manual match, the relative errors of wellbore storage coefficient and dissociation factor by the proposed method are 4.863% and 1.933%, respectively. The proposed well testing and DL method is proven to be suitable for problem inversion of natural gas hydrate wells, which may provide a new tool for engineers to understand the natural gas hydrate reservoirs.
A Non-Portland Cement System: A Step Forward Towards Sustainability of Oil Well Cementing
Authors: Abdelaal Ahmed , Elkatatny Salaheldin , El Fattah Ahmed M. Abd 
Published: October 2023

Abstract
Although ordinary Portland cement (OPC) is widely used in oil well cementing for different applications such as zonal isolation and plugging, it does have technical and environmental drawbacks. Portland cement is responsible for approximately 8% of the global carbon dioxide (CO2) emissions and consumes massive energy while manufacturing. Geopolymer cements, which are made from non-traditional, nonOPC ingredients, have garnered attention as potential candidates for oil well cementing due to their low CO2 footprint, and less energy consumption. This work introduces a proposed non-Portland cement system that totally replaces Portland cement using volcanic tephra (VT) activated by an alkaline solution. The study started by collecting, crushing, and sieving VT until getting fine VT powder. Rheological properties, unconfined compressive strength (UCS), Poisson's ratio (PR), and Young's modulus (YM) were also evaluated for the developed formulation. Sedimentation evaluation was conducted using the API method. The developed VT based geopolymer used sodium hydroxide (NaOH) solution and VT. The 24 h UCS was 3,132 psi with a PR of 0.29 and a YM of 7.69 GPa. It has a thickening time of 3.5 h without using any retarder at 170°F. The density variation between the top and bottom sections was only 0.65 %. This work introduced a new cement system made of VT without any processing except milling and sieving. This reduces the overall carbon footprint, and costs of oil well cementing operations. Moreover, it solves some technical problems associated with the use of Portland cement.
Great Opportunities for Young Professionals in Energy
Authors: Ershaghi Iraj , Paul Donald L. 
Published: October 2023

Abstract
"Scientists discover the world that exists; engineers create the world that never was." Theodore Von Karman
What will be the shape of the future in terms of energy use? What will be the sources of energy? What will be the major changes happening in the energy fields, what changes will result from engineering innovations, and how can AI and digital technologies change the energy engineering fields? Are there still opportunities for petroleum engineering graduates? How should the PTE curriculum be changed?
The combination of Energy Transition and AI are two areas that will materially impact the shape of the future of energy. Integral will be the developers, scientists, and engineering professionals, involved in innovating new directions, and therefore, more talent must be recruited and developed to add to the workforce who can impact these areas.
With regard to the forecasts of future energy and supply, major international organizations such as IRENA and IEA, are of the opinion that despite positions taken by some interest groups, the immediate phasing out of fossil energy is unrealistic. However, more immediate progress is needed to reduce the carbon intensity and emission levels from energy production and use. Advancing the development of capabilities such as economic direct air capture processes, converting the CO2 from power plants and convenient personal and public transportation to other useful products, and planning subsurface storage of CO2 at scale, are all likely to be needed to curb the global CO2 emissions loading.
These all create great opportunities for the advanced subsurface and operational expertise needed to drill, complete, and produce wells to communicate with subsurface storage systems. Also needed are more chemical engineering innovators and talents to focus on economical (DAC), Direct Air Capture, solutions, and carbon dioxide conversions.
In parallel, the advent of AI applications is revolutionizing how we can conduct oilfield operations and process dynamics. Major educational content and training changes can make petroleum engineering professionals perform functions with lower carbon emissions. This creates new classes of opportunities for society and energy-related professionals.
Integrating Learnings from Matrix-Acid Stimulation of Smart Liner Completions – A Template for the Future
Authors: Mogensen K. 
Published: October 2023

Abstract
Smart Liners rely on the limited-entry principle where a number of small holes act to distribute acid along the un-cemented reservoir section. Over the past two years, this technique has become a key method for matrix-acid stimulation of ADNOC's carbonate reservoirs. The objective of this paper is to summarize the learnings from more than 100 deployments and tie together the key elements of the hole spacing design, the stimulation job execution, and the performance monitoring.
A software algorithm generates the hole spacing design to honor a predefined acid flow distribution along the drain length. Quantification of the stimulation efficiency is addressed in several ways. First, the baseline well performance is established with production tests covering several months and in some cases accompanied by a pre-stimulation production logging test (PLT). The stimulation job is then analyzed and compared against a wormhole model to derive the transient injectivity improvement versus acid volume pumped. After the stimulation, the stabilized performance is analyzed in terms of production testing and occasionally a pressure buildup survey and a PLT.
Results have so far been very encouraging. Smart Liners have been deployed predominantly in oil producers and water injectors but a few implementations have targeted tight gas reservoirs. A typical steady-state productivity gain is 100-150% above the baseline unstimulated well and the technique consistently outperforms conventional matrix-acid stimulation techniques. The post-stimulation PLT's show that the entire wellbore contributes to flow, even in extended-reach wells. The majority of the efficiency improvement seems to occur with an acid coverage of 0.5 bbl/ft but some wells benefit from higher acid dosages. A wormhole model developed specifically for this completion-stimulation method can reproduce the observations and helps guide designs of future stimula0tion jobs by suggesting modifications to the hole spacing, which will improve the performance improvement using less acid volume.