bluuebunny/crossref_metadata_2025 huggingface dataset:
Effects of Pipe Rotation on the Performance of Fibrous Fluids in Horizontal Well Cleanout
Authors: Garcia Sergio , Mendez Michael , Ahmed Ramadan , Karami Hamidreza , Nasser Mustafa , Hussein Ibnelwaleed
Published: September 2022

The deposition of rock cuttings is a problem commonly faced during drilling, completion, and intervention operations. Using polymer-based fluids is a common technique to improve horizontal downhole cleaning. However, these fluids cannot always guarantee an efficient wellbore cleanout. One way to enhance cleanout efficiency is by rotating the drill pipe to mitigate the settling of solids and facilitate their removal. However, drill string rotation often increases equivalent circulating density (ECD). Therefore, this study explores how the impact of rotation on hole cleaning can be synergized by using fibrous fluids to perform cleanout at reduced rotational speeds with limited impact on ECD.

The flow loop utilized for this study consists of a 48-ft long eccentric annular (5" × 2.375") test section. Each experiment began by forming a stationary bed of natural sand (average diameter of 1.2 mm) in the test section. High-viscosity and low-viscosity polymer-based suspensions with and without fibers were used. Drill pipe rotation speed was varied from 0 to 150 rpm. In each experiment, the flow rate was increased from 35 to 195 gpm stepwise. The equilibrium bed perimeter was measured at every test flowrate until a complete bed cleanout was achieved. As part of the test, flow rate, pressure gradient, and equilibrium bed height were measured. Rotational viscometers were used to measure fluid rheology before and after each test.

Fiber particles improve the carrying capacity of the fluid by reducing the settling of solids and minimizing the re-deposition of particles. The results demonstrate the effectiveness of fiber in synergizing the effect of pipe rotation on hole cleanout performance in horizontal wellbores. The impact of fiber is more pronounced when used with low viscosity fluid. The cleanout performance of the low-viscosity fluid amplified significantly with rotation, almost entirely cleaning the bed at 75 gpm and a rotational speed of 50 RPM, compared to more than 195 gpm without rotation. Even more improvement could be achieved by adding a small amount of fiber (0.04% wt/wt). Furthermore, the fiber improved the cleanout performance of the high-viscosity fluid. The enhancement, however, was not as noticeable as with the low-viscosity fluid. In general, rotation combined with low-viscosity fibrous fluid exhibits the most effective sand cleaning performance. Rotating the pipe re-suspends the settled solids, which are then carried away by the fluids. Fiber particles enhance the fluid's ability to carry solids.
Pros and Cons of Saline Aquifers Against Depleted Hydrocarbon Reservoirs for Hydrogen Energy Storage
Authors: Delshad Mojdeh , Alhotan Muhammad , Batista Fernandes Bruno Ramon , Umurzakov Yelnur , Sepehrnoori Kamy
Published: September 2022

Hydrogen (H2) is an attractive energy carrier and its true potential is in decarbonizing industries such as providing heat for buildings and being a reliable fuel for trains, buses, and heavy trucks. Industry is already making tremendous progress in cutting costs and improving efficiency of hydrogen infrastructure. Currently heating is primarily provided by using natural gas and transportation by gasoline with a large carbon footprint. Hydrogen has a similarly high energy density but there are technical challenges preventing its large-scale use as an energy carrier. Among these include the difficulty of developing large storage capacities.

Underground geologic storage of hydrogen could offer substantial storage capacity at low cost as well as buffer capacity to meet changing seasonal demands or possible disruptions in supply. There are several options for large-scale hydrogen underground storage: lined caverns, salt domes, saline aquifers, and depleted oil/gas reservoirs where large quantities of gaseous hydrogen can be safely and cost-effectively stored and withdrawn as needed. Underground geologic storage must have adequate capacity, ability to inject/extract high volumes with a reliable caprock. A thorough study is essential for a large number of site surveys to locate and fully characterize the subsurface geological storage sites both onshore and offshore.

A non-isothermal compositional gas reservoir simulator and its suitability for hydrogen storage and withdrawal from saline aquifers and depleted oil/gas reservoirs was evaluated. The phase behavior, fluid properties, and petrophysical models were all calibrated against published laboratory data of density, viscosity, relative permeability, and capillary pressure for a given site. History-matched dynamic models of two CO2 injection field projects in saline aquifers and one natural gas storage in depleted oil reservoir were considered as hypothetical hydrogen seasonal storage sites. The results revealed the need to contain the stored working gas volume because of high mobility of gaseous H2 with an integrated approach of site selection and its geological features, well locations, and the need for pump wells to maximize the capacity and deliverability.
Implementation of Autonomous Inflow Control and the Effect on Carbon Intensity
Authors: Elseth Geir , Martiniussen Ingvild Berg , Halvorsen Martin , Årland Kristine , Wesenberg Margrete Hånes , Nogueira Elysio Mendes , Erlandsen Sigurd Myge
Published: September 2022

A lean approach for qualification of inflow control is presented, involving full-scale experimental tests. The experimental data are converted into optimized well design by a simple and robust workflow, incorporating internally developed software tools for pressure-drop modelling and for well modelling with inflow control. Production data from several Equinor operated fields are analyzed, and the increased oil recovery, as well as the impact on CO2 intensity, is discussed.

Results from a full-scale qualification test campaign including five different autonomous inflow control devices (AICD) are presented. The intended application is a special case with high expected production and high pressure, in nearly vertical wells, which is unlike any of the more than 175 wells with AICDs in Equinor. The ability to choke gas and allow high oil production, as well as other selected qualification criteria, were examined for the five, already commercially available, technologies in a benchmarking study.
Coupled Flow and Geomechanics in Reservoirs with Complex Fractures Using Embedded Meshes
Authors: Chen Jungang , Wu Kan , Killough John
Published: September 2022

Conventional modeling of coupled flow and geomechanics in fractured reservoirs requires computation meshes conforming to the fracture geometry, which not only needs complicated gridding techniques but consumes a huge amount of computing resources. The objective of this paper is to present a numerical model that is able to efficiently model coupled porous flow and poroelastic effect in fractured reservoirs with complex fracture distributions. In this paper, embedded discrete fracture modeling (EDFM) is used to model fluid flow in fractured porous media and an extended finite element method (XFEM) is utilized to model displacement discontinuities arising from fractures. To model fracture aperture changes during depletion, a proppant model with linear elasticity is assumed. Moreover, to cope with complex fractures, we consider two basic types of fracture junctions, one is the ‘X’ type junction where two fractures intersect each other, the other is the ‘T’ type fracture where one fracture is captured at the fracture tip by the other without crossing it. Special treatment is performed to preprocess two types of fracture junctions and any combination of these two. The model is validated by analytical solutions as well as cases from other publications. We also present horizontal well production cases where hydraulic fractures intersecting with natural fractures.
Intelligent Application of Computer Vision and Data Analytics to Optimize the Separators Cleaning for Unconventional Reservoirs
Authors: Parizek Jason , Popa Andrei , Tam Soong Hay
Published: September 2022

The reliability of the production operations depends not only on the well performance but also on the effectiveness of the surface facilities to transport and separate the produced fluids. In the case of the unconventional reservoirs, the completion treatments placed to stimulate the long horizontal wells require large volumes of proppant and water. During flowback and even later in the life of the well, fractions of the proppant makes its way to the surface and into the separators. Large accumulations of sand reduce the ability of the separators to perform as designed, impacting production, and requiring complete shut-down for cleaning to restore their original capability.

The work introduces an intelligent end-to-end workflow integrating computer vision and data analytics to automatically interpret thermographic images, identifying when a production separator needs condition-based maintenance. The new approach leverages infrared thermography pictures taken from hundreds of separators in an unconventional asset and automates a labor-intensive process to make objective maintenance decisions. Contrasted to the manual method, where vessels were taken offline, visually inspected, and cleaned out on time-based maintenance schedules, this work provides an accurate visualization of the sand level using computer vision.

The study demonstrates who how integration of digital technologies such as computer vision and data analytics enable optimization of maintenance work. The application showcases the business impact not only through cycle time reduction and effort, by also enables better decision making and optimization of resources.
A Passive Flow Control Nozzle for Water Choking Application
Authors: Zhu Da , Soroush Mohammad , Rosi Giuseppe , Scott Ryan
Published: September 2022

Reducing water production is the primary problem in the oil and gas industry. There are a few flow control technologies with moving parts available on the market to choke back water. However, the main issue with those technologies is the potential of plugging and scaling. In this paper, we will introduce a novel passive flow control nozzle, which has no moving part inside. All the choking is implemented through its internal geometry. Therefore, the risk of plugging and scaling will be significantly mitigated.

In this paper, a passive flow control nozzle designed specifically for water choking will be presented. Design philosophy in fluid mechanics will be introduced in detail. The results of Computational Fluid Dynamics (CFD) and physical flow loop testing will be shown to evaluate the performance of the technology. It is shown that a passive choking nozzle can choke back more than 40% of water compared to an orifice while maintaining oil production rates. We will also perform simulation case studies to compare conventional slotted liner completions with the completions equipped with a passive choking nozzle (PCN). We will show that the nozzle can effectively choke back water and promote oil production in a long horizontal well. Finally, we will briefly discuss how the passive nozzle can mitigate well-known issues such as scaling and plugging.
Numerical RTA Extended to Complex Fracture Systems: Part 2
Authors: Lia Carlsen Mathias , Curtis Hays Whitson
Published: September 2022

This paper is a continuation of the work presented in URTeC 3718584 (Carlsen & Whitson, 2022), and focuses on practical usage of ‘fractional RTA’ theory when applied to both simulated data and field data from the SPE data repository. Most of the theory presented in Part 1 is kept for completeness.

An inherent assumption in most industry RTA is equally spaced fractures. However, as shown in several field studies (Raterman 2017, Gale 2018), the distance between individual fractures tends to be unevenly spaced along the wellbore (e.g., "fracture swarms"). In this paper, we extend the original numerical RTA workflow proposed by Bowie and Ewert (2020) to account for uneven fracture spacing.

Acuna's (2016, 2020) heterogeneity parameter, delta (δ), is introduced to generalize the linear flow parameter (LFP) to account for complex fracture systems (LFP’ = Akδϕ1-δ = 4nfhxfkδϕ1-δ). For evenly spaced fractures, δ = 0.5, simplifying LFP’ to the familiar LFP = A√k = 4nfhxf√k. For uneven fracture systems, 0 ≤ δ ≤ 0.5.

With known (a) well geometry, (b) fluid initialization (PVT and water saturation), (c) relative permeability relations, and (d) bottomhole pressure (BHP) time variation (above and below saturation pressure), three fundamental relationships exist in terms of LFP' and OOIP. Numerical reservoir simulation is used to define these relationships, providing the foundation for numerical RTA, also wells with complex fracture systems. Namely, that wells: (1) with the same value of LFP', the gas, oil and water surface rates will be identical during infinite-acting (IA) behavior; (2) with the same ratio LFP'/OOIP, producing GOR and water cut behavior will be identical for all times, IA and boundary dominated (BD); and (3) with the same values of LFP' and OOIP, rate performance of gas, oil, and water will be identical for all times, IA and BD. These observations lead to an efficient, semi-automated process to perform rigorous RTA, assisted by a symmetry element numerical model.

The numerical RTA workflow proposed by Bowie and Ewert solves the inherent problems associated with complex superposition and multiphase flow effects involving time and spatial changes in pressure, compositions and PVT properties, saturations, and complex phase mobilities. This paper extends the approach to complex fracture systems that can be described by the Acuna parameter δ.

Numerical RTA workflow decouples multiphase flow data (PVT, initial saturations and relative permeabilities) from well geometry and petrophysical properties (L, xf, h, nf, φ, k, δ), providing a rigorous yet efficient and semi-automated approach to define production performance for many wells. Contributions include a technical framework to perform numerical RTA for unconventional wells, irrespective of fracture spacing. Semi-analytical models, time, and spatial superposition (convolution), pseudopressure and pseudotime transforms are not required.
Meet us Halfway – A Young Engineer's Thoughts on How to Make Petroleum Engineering a Cool Profession
Authors: Rahi Samir
Published: September 2022

Young people don't want to work in oil and gas.

Despite above average salaries and a resurgence in hiring, the industry faces a systemic, immediate risk of talent shortage due to changing public sentiments. This paper seeks to understand why new graduates are eschewing these types of careers, what paths they are currently following, and how alignment with their priorities may improve the industry's hiring prospects.

This paper is in part a response to two previous SPE publications written by 2016 SPE President Dr. Nathan Meehan: 2019's The End of Petroleum Engineering as We Know It and 2021's It's Not the End of Petroleum Engineering. Whereas the previous papers address this problem from the industry's point of view, this new work centers around the perspective and motivations of the young engineering graduates. Claims are also reanalyzed and recontextualized using additional studies and data.

Research and sources are augmented by the authors direct experience as a recent engineering graduate and his current roles with a Texas-based startup accelerator and a hard technology startup, as well as extensive interactions with recent petroleum engineering graduates and oil & gas industry professionals.

The additional data and analysis lead to the identification of four core pillars upon which young engineers base their decisions when selecting a place to work:

Innovativeness Ethicality Proactivity Inclusiveness

From a detailed discussion of these pillars, a three-tiered advocacy is developed to revitalize young graduates’ perception of oil and gas and modify existing recruiting and early career development practices. The recommendations provided can thus serve as a starting point for oil and gas companies to reassess their approach and thinking towards the acquisition and retention of new talent.
Production Technology R&D: Insights from Upstream Research
Authors: Al-Mutairi Saad M. , AlTammar Murtadha J.
Published: September 2022

Worldwide, research and development (R&D) programs have long been an integral part of most oil and gas companies. Large and small oil companies alike continuously perform several R&D activities on some level to improve their operations and services. With the advent of technology in recent years, companies are increasingly recognizing the competitive advantage that R&D provides to their core businesses. In this paper, we share insights from over a decade of R&D experience by the Production Technology Division (PTD) within Saudi Aramco's EXPEC Advanced Research Center (EXPEC ARC). The team has pioneered many technologies that significantly enhanced production operations, and helped in reducing operations’ carbon footprint in oil and gas fields. We highlight how the research team grew over time, and how they interacted and engaged with field proponents in their R&D work while providing several illustrative examples. We also discuss the focus and strategy of the team going forward.
Physics-Based 3-Phase Relative Permeability for Gas-Liquid Counter-Current Flow
Authors: Gupta Subodh
Published: September 2022

The objective of this paper is to present a fundamentals-based, consistent with observation, three-phase relative permeability model to describe flow more accurately in countercurrent movement of gas and liquids situation. While most flooding operations have both gas and liquids flowing in the same direction, in gravity dominated processes such as steam assisted gravity drainage (SAGD) or CO2 storage in water saturated reservoirs, often due to density difference the gases rise above and liquids flow down. This gives rise to a counter-current flow situation. It has been documented by a few researchers including Adebayo et al. (2017) and Prats et al. (2008). At the gas-liquid interface, the shear forces act to oppose movement of gas and liquids resulting in a slowdown in the flow of both. This slow-down or reduced flow is not captured in standard relative permeability curves which are typically generated using co-current flows.

In the current work, the approach adopted by Gupta (2021) for a mechanistic 3-phase flow model is used to develop relative permeability expressions for gravity-incorporated flow. To do this, three-phase core-annular laminar flow expressions are first developed in a single thin tube, then these flow expressions are aggregated for the entire pore volume represented by a bundle of tubes with varying tube sizes mimicking pore-size distribution. An irreducible water saturation, when water is the wetting phase, is also assumed.

The relative permeabilities obtained with counter-current flow considerations are compared with the ones presented in Gupta (2021) for co-current flow to highlight the difference. Additionally, the impact of these modified rel. perms is shown with an example SAGD problem resulting in a slower and more realistic growth of the steam chamber. Similar to the observation of Gupta (2021) this mechanistic model also indicates a natural dependence of rel. perms of the intermediate phase on temperature, which in literature has been a subject of much debate.

The novelty of the work is in development of a three-phase relative permeability model which takes into account gas-liquid countercurrent movement in porous media based on fundamentals of flow in fine capillaries. The significance of the work includes, aside from predicting results more in line with expectations in gravity-dominated processes, an explanation of temperature dependent relative Gupermeabilities of the intermediate phases. Also, unlike Stone-II method, it predicts a more realistic time dependent residual oleic-phase saturation for gravity drainage recovery methods.
Enhanced Reservoir Characterization of Complex Carbonates by Integrating Diagenesis with Petrophysical Properties
Authors: Al Subait Ali , Al-Nasser Kadhem , Alqahtani Najm , Agnia Ammar
Published: September 2022

Carbonate reservoir characterization is often challenging due to variable mineralogy, pore-geometry, texture, and diagenetic processes that modified the rock fabric and its petrophysical properties affecting rock typing, reservoir-potential evaluation, and deliverability prediction. This work implements a multidisciplinary petrophysical discrimination scheme that draws upon the diagenetic history of the rock to resolve such characterization challenges and optimize field development practices.

This study integrates sequence stratigraphy, core description, petrography, diagenetic analysis, mineralogy, routine core analysis (RCA), mercury injection capillary pressure (MICP) and wireline logs to define Diagenesis-Integrated Reservoir Rock Types (DI-RRT). The DI-RRT are established by delineating the continuous mineral phase, flow-dominant pore types, and main diagenetic processes. The data integration facilitated DI-RRT predictions, DI-RRT-constrained permeability and saturation-height modeling in all wells across the field.

This rock typing scheme effectively classifies reservoir potential and delineates the contrast in the reservoir's flow and storage properties. Diagenesis, linked to lithological and pore attributes, serves as an effective discriminant for rocks of similar depositional and lithological settings but contrasting reservoir behavior. This is evident in reservoir intervals of high-energy depositional facies, which showed distinct petrophysical trends due to post-depositional modifications. Calcitic DI-RRT of mainly grain-dominated fabric and moldic porosity exhibits consistently low-to-modest potential that varied in response to the intensity of leaching, cementation and compaction. On the contrary, dolomitic DI-RRT manifest six distinctive behaviors distinguished by pore-type, texture, replacive dolomitization, dissolution and cementation. The reservoir quality is significantly enhanced where replacive dolomitization accompanied intensive dissolution, even with patchy anhydrite cementation. This scheme enabled the identification and mapping of these high-productivity zones in wells across the field. It further granted a good match between log- and core-based predictions of permeability and saturation.

Integrating diagenesis with petrophysical rock types, wireline logs and field observations enhances reservoir characterization in complex carbonate reservoirs. It boosts current intellection of reservoir performance, identifies porosity-permeability and saturation trends with higher precision, and capitalizes on reservoir-quality zones during the field-development cycle. It further provides a roadmap to distribute petrophysical properties in uncored wells and 3D models optimizing subsequent static and dynamic models.
Evaluating Performance and Energy Efficiency of Hybrid Cyclic Steam Stimulation Technologies with a Novel Experimental Setup
Authors: García Hugo , Pérez Romel , Rodríguez Hector , Sequera-Dalton Belenitza , Ursenbach Matthew , Mehta Sudarshan , Moore Robert Gordon , Gutiérrez Dubert , Manrique Eduardo
Published: September 2022

An experimental program has been designed and executed to evaluate the performance of hybrid Cyclic Steam Stimulation (CSS) recovery methods. The overarching goal is to improve the energy efficiency and reduce the carbon footprint of CSS in Colombian heavy oil fields. Specifically, this work compares the impact that adding solvent or flue gas to cyclic steam injection has on the recovery of a recombined heavy live oil at a laboratory scale.

A novel experimental setup was designed to evaluate hybrid CSS methods, which allows displacement of fluids out of the core during injection cycles and the return of those fluids to the core during soaking and production periods, by the use of a ballast system. A CSS baseline test and two hybrid CSS tests were performed at reservoir conditions (RC) with recombined live oil and core material from a Colombian heavy oil field. Each test consisted of four cycles with the same amount of steam injection. The hybrid CSS tests consisted of a steam-solvent and a steam-flue gas hybrid test.

The CSS baseline and the hybrid CSS tests were successfully performed in the core pack with the injection of 0.12 pore volume CWE (Cold Water Equivalent) of steam per cycle, at core pressure near 680 psig and an initial core temperature of 45°C. In addition, steam-solvent and steam-flue gas hybrid tests injected near 0.01 and 0.05 PV (CWE) of solvent and flue gas per cycle, respectively. The steam front location during each cycle was identified with temperature profiles recorded along the core during the tests. Core pressures and fluid volumes displaced to and from the ballast were also recorded. Post-test core analyses allowed to estimate residual liquid saturations after each test. The addition of solvent or flue gas did not hinder the CSS oil recovery process which was in the order of 40% for all tests. The recovery, energy efficiency and carbon footprint of the hybrid CSS tests are compared to the CSS baseline case. Although a small amount of hydrogen sulphide (H2S) was detected at the end of the CSS baseline test, H2S was not detected in the produced gas of the hybrid tests.

The experimental program enhanced the understanding of hybrid steam cyclic methods and the impact of solvent and flue gas addition on the recovery, energy efficiency and carbon footprint reduction of heavy oil CSS recovery processes. These results assist in the quest of improving CSS performance and provide key data for tuning numerical models. This novel experimental apparatus is one of a kind as it captures the cyclic nature of fluid movement during CSS.
Rapid Detection of Super-Emitters Utilizing an IoT-Enabled Continuous Methane Emissions Monitoring System
Authors: Chakrabarti Aditi , Dauphin Mathieu , Andrews A. Ballard , Zielinski Lukasz , Rashid Kashif , Yuan Junyi , Speck Andrew , Huynh Adam , Power Justin , Nicolas Vincent , Gadot Raphael
Published: September 2022

Large methane emissions occur from a wide variety of sites with no discernable patterns thus requiring methodologies to frequently monitor for these releases throughout the entire production chain. To cost-effectively monitor widely dispersed well pads, we describe a continuous monitoring system based on the Internet of Things (IoT) to leverage cost-optimized methane concentration sensors permanently deployed at facilities and connected to a cloud-based interpretation platform. Testing at controlled methane release facilities enabled the validation of the sensor performance; fidelity of the atmospheric dispersion modeling underlying our interpretation; and the overall system performance in detecting, localizing, and quantifying methane releases.
A Systematic Photo Documentation of Drill Bit Forensics Applied to Motor Back-Drive Dynamics Case Caused by Auto-Driller Dysfunction and Formation Effect
Authors: Sugiura Junichi , Jones Steve , Pastusek Paul
Published: September 2022

North America shale drilling is a fast-paced environment where downhole drilling equipment is pushed to the limits for maximum rate of penetration (ROP). Downhole mud motor power sections have rapidly evolved to deliver more horsepower and torque, resulting in different downhole dynamics, such as motor back-drive drilling dynamics. This paper investigates the root cause of the motor back-drive dynamics and the bit/BHA damage caused by this.

High-frequency (HF) compact drilling dynamics recorders embedded in the mud motor bit box and top sub provide unique measurements to fully understand the reaction of the power section under load relative to the type of rock being drilled. 3-axis shock, gyro and temperature sensors placed above and below the power section measure the dynamic response of power transfer to the bit and associated losses caused by motor back-drive dynamics.

Formations with high interfacial severity pose more of a challenge due to the rapid change in formation strength. The torsional energy stored and released in the drill string can be high due to surface rotation-speed/torque output and downhole mud-motor speed/torque. Torsional drill string energy wind-up and release results in variable power output at the bit, inconsistent ROP and rapid fatigue on downhole equipment. Detailed analysis of the high-frequency embedded downhole sensor data as well as Electronic Drilling Recorder (EDR) data provides an in-depth understanding of mud motor dynamics. In one of the "Delaware Basin" field examples from Loving County, Texas, the root cause of the motor back-drive dynamics was identified.

A systematic photo documentation of drill bit forensics was performed to precisely document the bit damage from this type of drilling dynamics. The auto-driller weight-on-bit (WOB) and ROP setpoints were examined along with the downhole sensor data and EDR to pinpoint the root cause of drilling dysfunction. A drillstring analytical model was used to predict the torsional natural frequencies, which are compared against the sensor-observed torsional oscillation frequencies.

This paper reports a unique case of motor back-drive drilling dynamics caused by auto-driller dysfunction and formation effects. Additionally, a systematic photo documentation of drill bit forensics was applied to thoroughly document motor driven bit damage.
A Case Study on Integrated Downhole Logging Suite to Diagnose Multi-phase Flow and Improve Multi-Reservoirs Flow Allocation
Authors: Abdul Latif Azzad Hafiz , Giniyatullin Artur , Sidek Sulaiman , Mustafa Kamal Mohd Akmal , Zakeria Ahmed Nabil , Mohd Amin Farid , Abdul Rahman Hazrina , Nasron Budi Mawardi
Published: September 2022

This paper discussed Operator's experience on integrated downhole logging suite to diagnose multi-phase flow and to improve multi-reservoirs flow allocation in deviated wells, offshore Borneo Island. Field A is located in the West Balingian geological province of the Sarawak Basin, 140km offshore Bintulu in a water depth of 165ft. It was discovered in by Exploration Well #1 (EW#1), followed by downflank Appraisal Well #2 (AW#2) in 1982 and second Appraisal Well #3 (AW#3) in 2000, to address some of the significant subsurface uncertainties impacting on the field development plan. Phase-1 development wells (e.g. DW#1 and DW#2) was drilled and completed in 2014, with 7″ × 4-1/2″ cemented liner as lower completion across the clastic reservoirs. During pre-development in 2016, additional perforation in DW#1 oil zones were added whereas additional perforations in DW#2 oil zones were added in 2019. The two (2) relatively new wells produce commingled from several oil-bearing and gas-bearing zones. Developing highly compartmentalized multi-stacked reservoirs via simplified well completions, poses a great challenge for subsurface data acquisition when it comes to determining production allocation, managing flow assurance issues, understanding reservoir connectivity, surveillance of individual well performance and generating total field production forecasting.

Conventional production logging result conducted in 2016 was unsatisfactory to explain some of the wellbore and reservoir flow peculiarities. Since it was important to know which zones contributed to the production, diagnostic of wellbore/reservoir flows and coupled with well integrity issues, Spectral Acoustic Logging with Thermo-Hydrodynamic Modeling was conducted to obtain the valuable information and to perform well/reservoir diagnostic. Remote platform location put an additional challenge to the logging campaign, as such the logging program was customized to satisfy the logging objectives while comply with HSE requirement.

The collaborative approach between Operator and Service provider as solution partners, established a new finding for the formulation of remedial treatment to increase production and recovery from the wells by ensuring that each well operates to the maximum of its abilities.
A Revolutionary Advanced Displacement System for the Challenges in the 21st Century
Authors: Detiveaux Joey , Stanford Jack
Published: September 2022

Following the 2010 Macondo Prospect oil spill in the Gulf of Mexico, the more stringent regulations for offshore oil and gas operations required an entirely new approach to wellbore cleanout ahead of the completion phase. With all previous practices and chemistries effectively ended, the task was to develop a new, reliable, sufficiently dense, environmentally friendly, clear-brine displacement system that would address the challenges of cleaning out aqueous- and non-aqueous-based drilling fluids as well as perform in the elevated pressures and temperatures of ultra-deepwater operations in the Gulf of Mexico, Brazil, and West Africa.
Experimental Investigation of Acid Job Limit in Fractured Sandstone Formations
Authors: Karazincir Oya , Li Yan , Zaki Karim , Johnson Andrew , Williams Wade , Rijken Peggy , Rickards Allan , Hathon Lori
Published: September 2022

The goal of this study was to assign an operational limit to the number of acid jobs applied to a given well considering the effects of remedial acid treatments on propped fracture conductivity and near-frac face formation permeability, parameters that impact the skin factor. The Frac Face Damage (FFD) conductivity test unit introduced in previous publications was used to assess the change in formation permeability near the fracture face, as well as proppant pack conductivity. First, a test with field core without acid treatment was conducted as a control experiment to display the impact of closure stress on proppant embedment, fines generation, proppant pack compaction. This test showed stable proppant conductivity with slight permeability reduction at the formation face towards the end of the stress hold. Test duration and flow step lengths were kept identical to the acid tests for comparison purposes. Tests with eight acid cycles resulted in permeability gain at the fracture face with the early acid cycles followed by an accelerated drop in frac face permeability and proppant conductivity. Acid tests were conducted using fresh core and pre-damaged core and test results were compared to the control test. Skin value was calculated using a semi-analytical numerical model and the productivity index was estimated following each brine or acid injection cycle. The results clearly display benefit from acid stimulation during the initial acid cycles, followed by a sharp decline in the uplift with increased embedment that marks the acid limit. Post-test analysis of core material support formation of a deeper proppant embedment zone at the fracture face for the system that was acidized eight times, compared to the unacidized propped formation/proppant assembly.
Coining a New Concept: Drilling in Incompatible Conditions
Authors: Brahimi Oussama
Published: September 2022

This paper defines the concept of "Drilling in Incompatible Conditions" and how its identification can help in the inclusion of unconventional drilling fluids and technologies, in the planning phase or as a contingency plan. These technologies include casing and liner drilling, MPD, UBD, HPWBM, and their combination (ex: MPCD). This paper also presents a method to point out whether a given drilled section is compatible with overbalanced conventional rotary drilling – referred to as conventional drilling on this paper.

Identification of drilling incompatibility starts from a basic definition and widens based on field case histories of drilling using unconventional drilling methods (which means fields that have parameters incompatible with conventional drilling) or from cases in which an unplanned contingency casing was used. The parameters influencing the usage of these methods are used as inputs in machine learning. While the technological complexity level of the techniques in use can be divided into as many as four categories based on logistical and cost considerations. Only level 1 - conventional drilling - is in the scope of this work.

Machine learning classification algorithms are used to predict if the conventional drilling method is incompatible with parameters designated as input values, such as heterogeneity of lithologies in a drilled section, the presence of problematic drilling formations (mobile/reactive), presence of weak formations, formation temperature (high, moderate or low), formation pressure (over/under-pressurized), formation permeability and presence of natural fractures, and the ERD value. The outputs will present themselves as a binary value (Compatible/Incompatible). The inputs can be classified into continuous, binary, and ordinal data. This model provides insights on whether geological and operational parameters are too complex for conventional drilling, thereby avoiding drilling based on trial and error.

This work will fill the gap in terms of quantifying the complexity of a drilled section, both operationally and geologically, and deals with it from a relativity point of view with respect to the level of technology implemented through the usage of machine learning. This new concept will help drilling engineers be more efficient by answering complexity issues before the commencement of drilling. This will lead to cost savings and enhanced profitability by designing a wellbore with the least sections possible. Besides, this terminology reflects the definition of sustainability which is of utmost importance not just from the technical point of view.
Understanding Wettability of SiO2-Brine-CO2 System Using Modified DLVO Theory and its Applications in Carbon Geo-Sequestration Processes
Authors: Agrawal Bhautik
Published: September 2022

The reduction of Carbon footprints without hindering the evolution of the fossil fuel industry is the subject of prominent attention and research these days. In multi-phase rock-fluid systems, the wettability characteristics play a substantial role in determining the trustworthiness of underground reservoir formations for holding CO2 in situ for Carbon Geo-sequestration applications. Despite several struggles over the modern years in recognizing the aspects such as the information on the wettability of systems comprising CO2 under supercritical conditions and the zeta potential over the brine- CO2 film interfaces, inferring the wettability of the complete arrangement are crucial uncertainties and voids in our existing knowledge. Again, one needs to deal with the concepts of wettability and capillary pressures to understand the suitability of a formation for carbon sequestration. This study focuses on the sequestration of carbon in deep saline brine reservoirs. Under the intense pressure and temperature situations in these formations, CO2 can exist in a supercritical state and thus have a liquid-like density, enabling efficient utilization of the pore spaces in those formations.

In this research, a mathematical model based on the modified DLVO (Derjaguin, Landau, Verwey, and Overbeek) theory is designed to provide a better insight into the wettability of supercritical CO2 systems by utilizing fundamental principles to evaluate contact angles. The base model has been modified in the course of the study to accommodate for the properties of supercritical CO2. This model can also take up the experimental contact angle measurements as an input to anticipate values of critical properties that are presently unfamiliar, as they are challenging to analyze, such as the zeta potential on brine- CO2 interfaces. This model could also predict the suitability of geological reservoirs for carbon sequestration by evaluating the wettability under known conditions.
Waterflood Optimization on the West Siberia Field with Hydrodynamic Modeling
Authors: Dormenev Vladislav
Published: September 2022

Waterflooding is the main method of developing oil fields both in Western Siberia and in most other oil-producing countries. Most of these fields located in Russia are mature. Creating new technologies or optimizing the existing ones is the key to the effective development of residual hydrocarbon reserves. Optimization of a waterflood pattern is one of the main tasks of the oil industry. It implies planning and implementing a set of measures in the field that will affect the waterflood pattern and either increase the oil recovery factor, production or optimize the complex technical-economic parameter.

The purpose of the work is to increase the efficiency of oil field development by optimizing the waterflood pattern by means of hydrodynamic modeling on the example of the Western Siberian field.

Waterflood optimization can be accomplished by sidetracking or changing the development system. An integral element of a waterflood optimization system is always a field model, based on which the implementing different measures is planned. In this paper, hydrodynamic modeling was used to evaluate the effectiveness of waterflood optimization. It is considered one of the most powerful predictive tools available to reservoir engineers.

RN KIN software was studied, with the help of which the basic data about the field was obtained. The waterflood pattern was selected for the decision to implement a local measure. A hydrodynamic model was used to analyze the effectiveness of the measure. Waterflood pattern model of the field was built and adapted. Four measures, potentially aimed at increasing the efficiency of the waterflood pattern, were proposed. After carrying out calculations, the best of them was selected from a technical and economic point of view. Hydrodynamic modeling and calculation of development parameters were carried out in the Petrel software.

In the course of the study, the possibility of using hydrodynamic modeling to analyze the efficiency of the waterflood pattern was shown. Sidetracking of the longest length proved to be the most effective measure to increase cumulative oil production and reduce cumulative water production. Thus, the paper obtained results that can serve as a good basis for justifying the effectiveness of well intervention on the example of the oil field in Western Siberia.
Optimization of Machine Tractor Outfit: - Case of Disc Plough
Authors: Gebrekidan Biniam Zewdie , Demissie Meron Girma , Kolhe Kishor Purushottam
Published: September 2022

Agricultural mechanization in Ethiopia is found to be at minimum level mainly depending on draft animals and human drudgery. One of the factors affecting on tractor matching to a proper disc ploughs in different climate and soil conditions. The objective of this study was to optimize machine tractor outfit for some selected agricultural tractor with disc plough. Therefore, three models of disc plough with tractors 80 hp and 50hp on the 2nd and 3rd gears forward speeds of 1.18 m/s, 2.01m/s, 0.89 m/s, and 1.18m/s respectively was tested and ploughed in vertisol and sandy clay loam soil type. The results obtained during ploughing operation in vertisol soil type 80 hp with 4 bottom disc plough 66 cm disc diameter the field capacity, average pull force and average fuel consumption was 0.35 ha/hr, 17000N and 28 lit/ha respectively and 80 hp with 3 bottom disc plough 66 cm disc diameter the field capacity, average pull force and average fuel consumption was 0.52 ha/hr, 13500N and 21.8 lit/ha respectively. Sandy clay loam soil 80 hp with 4 bottom disc plough 66 cm disc diameter the field capacity, average pull force and average fuel consumption was 0.62 ha/hr, 11500N and 20 lit/ha respectively and 80 hp with 3 bottom disc plough 66 cm disc diameter the field capacity, average pull force and average fuel consumption was 0.52 ha/hr, 8500N and 23.08 lit/ha respectively. Sandy clay loam soil 50 hp with 3 bottom disc plough 66 cm disc diameter the field capacity, average pull force and average fuel consumption was 0.31 ha/hr 8500N and 19.2 lit/ha respectively and 50 hp with 4 bottom disc plough 50 cm disc diameter the field capacity, average pull force and average fuel consumption was 0.26 ha/hr, 7500N and 15.39 lit/ha respectively. Based on the performance evaluation results in vertisol soil type 80 hp tractor with 3 bottom disc plough 66 cm disc diameter and in sandy clay loam soil type 80 hp tractor with 4 bottom disc plough 66 cm disc diameter, 50 hp tractor with 3 bottom disc plough 66 cm disc diameter was the most appropriate for ploughing as it recorded the highest field capacity, low pull force and fuel consumption.
Integration of FOPID and Mayfly Algorithm for SEPIC with Multi-objective Functions
Authors: SHRUTHI A. , SRINIV A.
Published: September 2022

SEPIC DC/DC with a single stage converter is organized in this work. Still, there is an energy loss of the single-ended primary-inductor converter (SEPIC), there is a need for deriving the new algorithmic model with modern concepts. A novel intelligent optimization algorithm namely mayfly algorithm is approached with unique optimization capabilities i.e. recently proposed. The topology of chosen controller has the conjunction of FOPID and Multi-objective Mayfly Algorithm (M2A), which is named as M2A-FOPID. To succeed this outcome from converter, an optimized FOPID can be utilized. The classic Fractional-Order Proportional-Integral-Derivative (FOPID) controller under single operating conditions with single objective optimization is expanded to a multi-objective configuration. An enhanced mayfly algorithm with FOPID depends upon the position of multi-objective functional group, which is incorporated in the above mentioned converter. The reference voltage of the controller is tuned and the generated PWM is optimized by the M2A-FOPID model, which can be applied to SEPIC. It provides an enthusiastic research value. On the other hand, there are some inadequate explorations, and also it may easily fall into the local optimization problem. The targets of this work can be able for boosting up the performance outcomes of the mayfly algorithm and this optimized value can find out its application in FOPID controller for multi-objective problems. To inaugurate the multi-objective FOPID (MO-FOPID) controller optimization issue under various multiple working situations, the integral of the time multiplied absolute error (ITAE) index at both high and low working condition is further comprised as objective functions. The M2A-FOPID is coupled to the SEPIC model and the mutual effectiveness of this controller with the combined model is experimentally tested. Also, the improvement of exploration is verified using the simulation model that is established in MATLAB /Simulink.
Adaptations of two Psychotherapeutic techniques in the Cultural dynamics of Postnatal Depressive Women attending Post-Antenatal Clinic in a Teaching Hospital in Awka Nigeria
Authors: Abamara Nnaemeka Chukwudum , Obiora Nzube Benjamin , Vivalya Bives Mutume Nzazu
Published: September 2022

The study investigated the adaptation of two Psychotherapeutic techniques namely Meseron therapy and cognitive behavioural therapy in the cultural dynamics of postnatal depressive women attending a post-antenatal clinic in a Teaching Hospital in Nigeria. We enrolled two hundred participants randomly selected among Igbo women from South-East Nigeria suffering from postnatal depression. MT and CBT were used as psychotherapeutic interventions to alleviate the mental health condition of the women. The treatment modalities were modified in line with the cultural context of the study, across three domains for MT and eight domains for CBT, ranging from the patients’ cultural factors in the Igbo communities. The study is a survey, adopting a between-subject design and the data was analysed with a one-way analysis of variance. The findings revealed that the cultural adaptations of Meseron therapy were more effective than cognitive behavioural therapy in the treatment of nursing mothers suffering from postnatal depression. It was recommended that psychotherapists and mental healthcare practitioners should adopt these approaches to treatment in relation to the cultural dynamics of their patients.