bluuebunny/crossref_metadata_2025 huggingface dataset:
Well Life Extension Via Casing Corrosion Control
Authors: Yugay A. , Elsabbagh Dr. Fady , Maldonado J. N. H. , Yang H. , Vorozhikhin S. , Zhukin A. , Girgis F. , Alkarbi M. A.
Published: October 2023

Well casings are the main element of the well secondary barrier envelope. Ultimate well life is defined by the condition of the casings (since those are not replaceable comparing to tubing’s if cemented to surface). Casings are made from carbon steel and gets corroded if not properly protected. Cathodic protection addresses the exposure of the casings to the external corrosive environment but doesn’t help in the double casing ("shielded") area.

Due to the fact that complete fluid displacement with absolutely clean cement slurry behind the casing cannot be guaranteed and there is always a risk of contamination with the fluids pumped ahead (which gets trapped in the annulus and can create corrosive environment in stagnant conditions), the proposed solution assumes usage of corrosion control additives in the fluids pumped prior to the cement slurry to mitigate corrosion. Those includes oxygen scavenger, corrosion inhibitor and biocides.

Review of the corrosion logs confirmed there is a threat that needs to be properly addressed. The review was done for the double casing area of the wells that have both inner and outer casing evaluated by corrosion logs. The inner casing was evaluated by the conventional azimuthal ultrasonic or magnetic flux leakage logs, the outer casing was evaluated by the electromagnetic Eddy current based log. It was several cases observed with outer casing corrosion on the inner string while the outer string wasn’t corroded. That means that the casing got corroded externally due to the corrosion environment created in between two casings. Review of the cement logs across the same are shows lack of cement isolation and demonstrates contamination with other fluids pumped ahead of the cement. Those may include drilling mud, low-viscous pill, cement spacer. Lab analysis of the samples of the water used to prepare those fluids shows high oxygen content, comparing to the standard safe operating limits. Oxygen can act as a trigger for the corrosion and also can act as a consumable of the corrosion reaction. Keeping it under control may not only prevent corrosion, but also reduce it in case it still occurs.

This study proves the threat of the casing corrosion due to imperfect cement isolation based on the actual events. Proposed solution of the corrosion control via chemical treatment of the fluids pumped ahead of the cement slurry is dramatically cheap comparing to the overall well budget but has a strong direct positive impact on the ultimate well life. Recommended to be used by all operators complying to well double barrier policy.
Integrated Gas Asset Optimization System (IGAS) - Developing an Integrated Production Efficiency Optimization Tool Across Upstream and Downstream Process Lifecycles for a Gas Condensate Asset in Abu Dhabi
Authors: Al Maazmi J. , Mabrook M. , Al Badi M. , Al Bairaq A. , Mogensen K. , Al Suwaidi E. , Al Saeedi A. , Al Hareithi F. , Sivanandam S. , Al Yaaqoubi N. , Al Mheiri E.
Published: October 2023

IGAS is a project that aims to develop a digital network optimization model capturing the complete gas life-cycle of Reservoir A from its Upstream through the Downstream process flow. This submission focuses on the modeling efforts and the preliminary implementation of the model in a field trial to generate optimized production scenarios aimed to maximize condensate production in a reservoir developed under gas recycle strategy to form the basis for the development of an AI optimization tool.

IGAS model was built using commercially available solutions to integrate the upstream and downstream models. Model development was straight forward with commercial well performance and network modelling tools combined with process workflow simulators to develop upstream and downstream models, respectively. Those were assimilated in a single tool using an interconnection platform to facilitate integration of workflows. Post model integration, a field trial was conducted to validate the model’s accuracy in generating condensate maximization scenarios.

IGAS field trial was conducted over a period of 10 weeks. A scenario was generated in accordance with the expected well availability for duration of the field trial. Post field trial, two primary observations were made: An Adherence Score metric was created, which calculates how well the IGAS scenario was followed considering each well’s CGR and suggested IGAS rate. A direct correlation was observed between Condensate production and Adherence Score objective function, indicating that the more IGAS scenario is adhered to, the more condensate is produced.Condensate history matching exercise was conducted for the trial period duration, which observed an average error of 1.72% (model vs actual production). This was followed with an optimized scenario generated for each day of the trial period (actual wet gas production for given day was set as constraint to ensure fair comparison) in order to quantify the potential condensate production. This exercise observed an average additional condensate production of 2.2%, which could have been produced if the IGAS scenario was adhered to. Unlocking such value would require the installation of well choke actuators to facilitate instantaneous changes to the chokes.

IGAS serves a great example of the potential value that can be unlocked with modern day IAM (integrated asset model) solutions. More importantly, it sheds light to the importance of developing unmanned field operations (well choke actuators in specific), which maximizes the use of IAM solutions such as IGAS enabling instant implementation of suggested scenarios.
Numerical Investigation of Acid Stimulation Process in Carbonate Rocks with Heterogeneous Mineral Distributions
Authors: Jia Cunqi , Alkaabi Saif , Hu Jinchuan , Sepehrnoori Kamy
Published: October 2023

Acid stimulation is a common well stimulation technique for the effective development of carbonate reservoirs, in which the acid solution is utilized under the formation fracture pressure to increase formation permeability while bypassing damaged domains around the wellbore. This study is motivated to evaluate the effect of mineral heterogeneity on acidizing efficiency in carbonate rocks. The two-scale continuum model is employed to describe the mass, momentum, and energy change during the acid stimulation process. In particular, the solid phase mass conservation equation is extended to consider mineral compositions, including reactive minerals of calcite and dolomite and non-reactive minerals of clay and quartz.Results indicate that mineral heterogeneity can affect both the acid consumption efficiency to achieve a breakthrough and the optimum acid injection rate corresponding to the minimum pore volume to breakthrough. The acid stimulation curve is more sensitive to the content of reactive components. More acid solution is needed to stimulate the core sample with a less reactive component of dolomite. The optimum acid injection rate increases as calcite content increases. When the reactive mineral distribution is not continuous, such as vertical or layered distribution, the acid stimulation curve is complicated by the competing reactions between reactive minerals.
Turning Acid Treatments from Failure to Success Using Polymer-Free Single-Phase Delayed Acid: A Case Study of Complex Horizontal Well in Dolomitic Formation, UAE
Authors: Zakaria A. , Ruiz C. Sirlupu , Singh A. , Mahabir R.
Published: October 2023

Horizontal wells with long laterals and Inflow Control Device (ICD) completion drilled from artificial islands are adopted in an offshore field, UAE to boost hydrocarbon production from high-temperature Arab formation. High-temperature conditions, long lateral, heterogenous reservoir, ICD completion, and dolomitic formation provides harsh environment for a successful acid stimulation treatment. Previous interventions with regular 28 wt% HCl and conventional emulsified acid were conducted in one of these oil horizontal wells. Both acid treatments failed and resulted into no incremental production. The horizontal well was completed across a long lateral of 5,200 ft with 4 ½ in. liner equipped with ICD system with a high bottom hole temperature of 300°F, permeability range of 0.3 to 40 md, and average porosity of 15%. In this paper, we will discuss how the application of the new polymer-free, single-phase delayed acid fluid (PFDA) technology unlocks the full production potential of Arab formation.

Extensive laboratory testing including diffusivity testing, coreflow testing, and computed tomography scanning was conducted to evaluate the performance of the PFDA against regular HCl and emulsified acid. These tests proved that the use of PFDA would enhance the acid penetration in the dolomitic formation due to the retarded rate of reaction, maximizing reservoir contact. The tests also proved that 20% acid strength would be effective to create long dominant wormhole, bringing advantage to reduce corrosion package compared to the previous treatment using regular 28% HCl

The low friction of the new polymer-free, single-phase delayed acid (PFDA) enabled high pumping rate through Inflow Control Devices (ICD) completion during the entire treatment, which was previously a challenge due to high viscosity of emulsified acid. The PFDA was combined with a viscoelastic surfactant-based diverter to maximize lateral coverage in the heterogenous reservoirs. Software modelling was coupled with the extensive testing and the PFDA fluid technology to optimize job design, volumes, pumping rates, and diversion strategy. The integrated approach yields unprecedent stimulation success.

Post treatment analysis showed that the PFDA boosted the production by more than 1000 BOPD (140%) compared to no incremental production from previous acid stimulation treatments with conventional emulsified acid. The use of PFDA enabled high pumping rates up to 20 bpm compared to 12 bpm for emulsified acid, reduced the mixing time by 16 hours, and saved on associated cost and time.

The introduction of the new PFDA provides the industry a revolutionary fluid technology to unlock the full production potential of Arab carbonate formation. Moreover, the polymer-free, single-phase delayed acid simplifies operations, eliminates the need for diesel phase and associated HSE concerns, and reduces carbon footprints.
CO2 Injector Integrity: The Comparison of Semi-Analytical Solution with FE Analysis of Near Wellbore Thermo-Poro-Elasticity Couplings
Authors: Barsukova Antonina
Published: October 2023

Depleted gas reservoirs in the North Sea offer an interesting potential for CO2 storage because the geology is understood and the infrastructure is in place. One of the key issue is to check that the wells which have been producers during the life-time of the reservoirs can now be used safely for cold gas injection. This paper contributes to this question by providing a workflow to analyse the possible failure and debonding between the casing and the cement during the injection phase. A classical analytical solution based on thermo-poroelasticity is proposed, assuming a vertical well, an axisymmetric stress distribution, and either plane strain during gas production, or plane stress during injection. This simplified solution is compared with the predictions of a commercial 3D finite-element (FE) code applied to the near well regions. The application concerns a well in a reservoir, off-shore The Netherlands. The analytical solution, easy to develop, is found to be of great help in shedding light on the FE predictions, which involves detailed but complex process to arrive at the solution. The integrity analysis is performed after completion, at the end of depletion and during CO2 injection. The analytical solution predicts debonding at the casing-cement contact and shear failure hazards in the cement, which are not identified with the numerical tool. This paper provides valuable insights into the application of numerical and analytical solutions, pros and cons for both approaches are discussed considering computation cost and setting up of the model.
Flexible Pipelines Risk Based Integrity Management Planning
Authors: Shahrustami M. Nadzeri M. , Anuar Karim Khairul , Hayati Hussien , Aishah Ali Noor Razak Siti , Anwar A. Samad Khairul , Firmann Nik Zulkefli Nik M. , Zahrin Zain , Salwanie Zakaria Nor
Published: October 2023

This paper shares on recent effort in PETRONAS on standardization of risk model and risk-based integrity management planning for its flexible pipeline assets. A semi quantitative approach is adopted in determining the likelihood of failure by using set of descriptors, coupled with the company standard consequence of failure descriptors to define risk of each threat and damage mechanisms. Screening of credible threats involves understanding on the function and impact of each to flexible pipelines components and compared against failure statistics and experiences in industry. Then, a guideline on the Integrity Management Plan (IMP) was established based on the risk rating i.e. High, Medium and Low, underlining respective inspection, monitoring and maintenance activities required to reduce and control the risk to As Low As Reasonable Practicable (ALARP). The result of this standardization effort on the risk model for flexible pipelines, the company easily can determine its flexible pipeline risk timely.

Meanwhile, with the IMP would enable the company to strategize and prioritize its resources to focus particularly to its high risk, thus high consequences flexible pipeline assets. In previous practice, each pipeline will be assessed based on engineering judgement through an exercise participated by various experts. While sometimes these criteria are not standardized from one pipeline to another, this exercise normally would take several days and sessions to complete due to the fact of lengthy review and challenge session to arrive to consensus on the final risk and its integrity management plan of each of its pipeline. Flexible pipelines integrity management is still considered new to the industry. This type of asset, originally installed on marginal fields with short lived economic life with very less or no maintenance at all. Nevertheless, most of these assets also have been operated beyond its design life as operators are continuously cutting down its production cost. Due to this, a robust integrity management system is required. It is imperative that with understanding on risk as well as exploring ways to maintain this kind of asset is becoming increasingly vital to balance between the risk of failure and cost to operate.
World Longest 7 in Single Trip for Multizones High Rate Water Pack Enhances Completion Strategy in Offshore Indonesia
Authors: Tokoh K. W. , Jatikusuma R. , Manalu D. N. , Yudis P. , Li C.
Published: October 2023

Multizones Single Trip Gravel Pack (MZ-STGP) completion has been mainly utilized in Mahakam field in Indonesia since 2012 to present. The system has been used as a sand control solution for its cost efficiency, the ability to complete multiple pay zones in a single trip and to provide zonal isolation for production selectivity for typical unconsolidated sands, poor sorting, and uniformity coefficient as well as very high fine content. The cost escalates when this requirement happens for multiple zones that may require multi run which needs longer rig time.

As of now, few of completions used to utilize the 9 5/8" system that normally require large bore and pumping more volume of fluid injected to deliver gravel pack slurry into wellbore. Meanwhile as part of drilling and completion cost efficiency, slimmer well architecture and completion system installation has driven by the needs for of a smaller borehole under various scenarios such as cases where 9 5/8" casing cannot reach planned depth and unlock additional reserves deeper below 9 5/8" casing shoe associated with well cost optimization for marginal gas wells at Mahakam.

This paper reviews on successful execution of 7″ Multizones Single String Gravel Pack system deployment, high rate water pack design, lessons learnt and required mitigation on the system itself while ideal deliver gravel pack slurry have to be in place properly at downhole. Further optimization is the Multizones Single String Gravel Pack system developed to unlock more potential sandy reservoir drilled with multi zones gravel placement treatment in order to reduce the rig time and preserve smaller 7in multizones single trip system by extended top bottom assembly to 445 m and service pipe length up to 425 m as world longest 7" MZ-STGP system to achieve optimum well cost economically.
Overview of Multi-Stage Fracturing Using Fiber Enabled Coiled Tubing Plug and Perf Method: First Deployment in Indonesia
Authors: Yudhanto G. , Asrul F. , Ultra D. , Saib E. F. , Aprilianto E. , Hidayat S. N. , Pramadana A. , Akbari A. , Hermawan F. A. , Agatha S. A. , Jenie J. , Gani E. E.
Published: October 2023

KS-HZ, onshore producer well, is the first horizontal well of one of operators in Sumatera, Indonesia. The well has been drilled since early 2020 but suspended due to drilling problems. The operator then decided to side-track drill and complete the well with multistage hydraulic fracturing. This project is planned to unlock oil potential from Telisa Formation (less than 3 mD permeability) and boost production performance. Transverse multistage hydraulic fracturing technique is widely used to enhance production from low to medium permeability formation, but it can be quite a challenge when applied to thin T formations (40 feet of thickness) that have soft and shaly sandstone properties. In this well, without adequate completion technology approach and over flushing the proppant in each single stage will have negative impact on production performance.

This paper will describe consideration of multistage fracturing design, a technology approach that used in the completion execution, and efficiency improvement. This includes coiled tubing (CT) and fracturing operations that covers: CT memory logging, CT wellbore clean up, stage optimization, stage spacing, CT abrasive jetting perforation, hydraulic fracturing, CT milling, and CT clean-out. In addition, the utilization of fiber optic enabled CT with pressure, temperature, tension and compression, and gamma ray modules enables operator to monitor real-time downhole parameter for accurate perforation depth placement within the small gap window. It will also help to calibrate frac design on each stage from the advantage of live downhole pressure monitoring during Diagnostic Fracture Injection Test (DFIT) analysis. CT abrasive jetting perforation was also selected to maximize reservoir contact and to reduces near-wellbore friction that minimize the possibility of proppant screen out.

A total of 7 stages of propped hydraulic fracturing method has been successfully placed without any placement failure. Approximately 881,000 lbs of proppant pumped into the Telisa Formation.

As a final point, this first deployment of multistage hydraulic fracturing with fiber optic enabled Coiled Tubing is proven to be unique solution to help the operator to gain additional production from challenging Telisa formation. This success elevates operator's confidence for future project and becomes golden experience for the nation to develop future multistage fracturing in same Telisa Formation across Sumatera Island.
Highly Thixotropic Engineered Cement Solution Helps Overcome Lost Circulation While Drilling Deepwater Exploration Well
Authors: Velasco A. , Segouffin J. , Duarte B. , Simental S. , Rowe M. , Major J. , Toranzo G. E. , Garcia S.
Published: October 2023

Loss of circulation while drilling can significantly increase the cost of drilling a well section. A lost circulation decision tree with robust and proven solutions is a tool that enables operators to address the risks and benefits of the treatments available. This paper describes the use of an engineered cement solution to solve an unexpected total loss of circulation situation without retrieving the drilling bottomhole assembly while allowing well operations to continue, during a deepwater exploration campaign in Mexico.

The highly thixotropic engineered cement (HTEC) systems are lightweight portland cement slurries tailored to exhibit low viscosity when shear stress is applied and develop gel strength rapidly as shear is removed. This enables the systems to penetrate formation fractures where rapid gelation occurs, after which the development of compressive strength delivers a hydraulic seal. A pre-drill risk assessment of lost circulation was built, and a lost-circulation decision tree was developed to have LCM solutions readily available, due to the logistics constraints of work in deepwater. An unexpected loss of circulation event occurred in the 12-1/4" hole section, the decision tree called first for an LCM treatment which was unsuccessful, maintaining losses of 500 bbl/h.

The HTEC system was pumped through the bottom hole assembly (BHA) and placed at the thief zone via a bullhead squeeze. A conventional cement spacer was used to separate the interfaces. The treatment was spotted at the thief zone and allowed to develop compressive strength for 7 hours, then tagged with the drill bit. The rig was able to break circulation with a rate of 2.4 bpm without recording any further losses.

The use of HTEC systems when other LCM systems have had no success, helps reduce drilling fluid cost and rig expenses when correctly engineered. Often a single treatment results in total control of the losses.
A Custom-Fit Approach for Temporary Well Suspension Saves Remedial Stimulation and Well Activation in North Kuwait
Authors: Bastaki Fahad Mahmoud , AlMatar Mohammed Ahmad Mohammed , Al-Bahar Zakaria , Chong Mizan BinOmar , Barki Jassim Hamed , Jamal Mariam , Al-Mehena Mehanna , Slama Mohamed Hedi , Badrawy Kareem , Molero Nestor , Sunagatov Rustem , Sebaih Mohannad Adel
Published: October 2023

Following the rig-based well testing stage, completion programs of high-pressure wells in North Kuwait call for well killing with heavy oil-based mud (OBM). The workover rig is then demobilized, and production flowlines are installed. Well activation plans are carried out riglessly, and coiled tubing (CT) is instrumental to bringing the wells back to sustainable production. One of the major drawbacks from this practice is the formation damage generated by the OBM, which often requires additional interventions for remediation.

To address this limitation, a new approach leveraging instrumented CT for temporary well suspension was recently implemented. Real-time downhole telemetry is enabled by an optical line installed in the CT pipe and used to accurately set a through-tubing inflatable packer (TTIP). Once the latter is anchored at the planned depth, above the interval open to the formation, CT is disconnected from the packer assembly, and the fishing neck is protected with a sand plug. CT is then retrieved to surface, and a slickline dump bailer is run to spot cement on top of the sand plug. Once the cement has set, CT is run to displace the wellbore to kill fluid.

Two pilot wells were selected to implement this new approach for temporary well suspension. Both wells had a maximum potential wellhead pressure in the order of 7,400 psi, and 15.0-ppg OBM was originally planned for well suspension purposes. Upon completion of the zonal testing program - which included initial stimulation, well activation, and flowback - instrumented CT was run with high-pressure rotary jetting to condition the TTIP setting depth and displace the wellbore with brine, after which, a shut-in wellhead pressure near 2,000 psi was observed. In the next CT run, TTIP was set close to the end of the production tubing, and critical stages, such as depth correlation, packer inflation, and packer anchoring testing were closely controlled via real-time downhole measurements. Additional verification of the TTIP effective seal was carried out before the CT was disconnected from the packer assembly through an inflow test relying on live downhole pressure monitoring. Once the TTIP released, the temporary suspension was completed following the methodology described above. Finally, the wells were observed at surface with zero pressure for more than 24 hours, receiving acceptance from the operator.

This alternative approach for temporary well suspension represents an innovative solution to bring wells back into production without additional restimulation or well activation. This methodology greatly relies on CT real-time downhole telemetry, and operators from the Middle East can benefit from the experience gained in this project.
Machine Learning Assisted Cement Integrity Evaluation During Plugging and Abandonment Operations
Authors: Camerini I. G. , Ferreira G. R. B. , de Souza L. P. B. , Hidalgo J. A. S. , Correia Tiago M. , Rodrigues A. S. , Batista J. H. G.
Published: October 2023

Due to the growth of Plugging and Abandonment operations, the challenges of assessing the integrity of the cement layer and the quality of its bond to the casing and formation increase consequentially. Hence, it is paramount to ensure that the wellbore is hydraulically isolated from the surrounding environment before permanently sealing the well. However, nowadays, this process depends on the skills of a specialist interpreting a vast amount of complex data acquired through logging operations, which turns the task human-dependent, error-prone, and time-consuming. Motivated by that cement evaluation task, ouronova, in partnership with Repsol Sinopec Brazil, is developing a computational tool to interactively assist the specialist in interpreting cement integrity logging data and the operator in optimizing the planning and management of Plugging and Abandonment campaigns. The so-called P&A Assistant software uses machine learning techniques that, through the work done so far, have shown to be a promising alternative to improve the accuracy and reliability and reduce the time of the cement sheath integrity analysis. The software is also prepared to work with logging data acquired in a through-tubing configuration, which represents a reduction in operational cost and time. The paper presents the software's initial module, presenting three different unsupervised methods (K-means, Bisecting K-means, and Gaussian Mixture Model) and input feature combinations, with the aim of optimizing the model. The main results of the work indicate that the methods implemented using the Cement Bond Long channel and Bond Index channel have better results when compared to the models combined with Variable Density Log and AIBK, with values above 0.7 for Rand Index and 0.5 for Silhouette Coefficient. For the unsupervised methods, the K-mean model had the best performance.
Improvement of Thru Tubing Gravel Pack Placement Techniques Enhancing Gas Potential for Offshore Fields
Authors: Choodesh A. , Chantarataneewat W. , Peerakham C. , Piyakunkiat N.
Published: October 2023

Sand production is naturally occurred in Miocene-Pliocene clastic reservoirs. To develop the well throughout the years of field experiences, sand production management during the very early and late stages of well life, as a result of depletion of reservoir pressure has brought up many challenges, especially in terms of field potential sustaining, well productivity and investment justification.

Thru-tubing gravel pack (TTGP) is one of the options considered for sand control remedy. Placing gravel into the annulus of tubing-screen and tubing- blank section which similar principle as circulation gravel pack and can be deployed in various methods using wireline, coiled tubing, or bull heading without the need for workover or rig operations. Based on field experience, the coiled tubing considers more efficient method for thru tubing gravel pack compared to wireline conveyance, i.e., using a dump bailer. But the drawback of conventional thru tubing gravel pack (TTGP) is the high skin value because the gravel only fill up in the annular section as above mentioning. Perforation damage still generate additional skin, smaller ID of the screen, finally end up with shorter well life expected.

The most effective placement techniques are by squeezing the gravel to pack in the perforation and possible void space in the reservoir with the coiled tubing. It has been proven method for minimizing the production of sand-fines, reducing perforation damage, and prolonging well life. But the successful squeezing the gravel to pack in the perforation and possible void space in the reservoir via coiled tubing the challenge operation, especially on 3-1/2" Monobore completion with 1.5" OD of coiled tubing. The improvement of the through-tubing gravel pack pumping technique, which focuses on improving gravel placement, addresses a problem that needs a solution with utilizing the existing equipment and services. To overcome this limitation, a concept of combining the gravel placement in both coiled tubing and annulus has been innovated, studied and evaluated to eliminate the problem of limited gravel placement.

This improvement of thru tubing gravel pack placement technique has been applied field where sand production is expected from both virgin formations and existing depleted zones. The gas potential gain from all implemented wells (11 wells) has observed at 62 MMSCFD at Maximum Allowable Sand Rate (MASR).
Machine Learning Assisted Fracture Network Characterization of A Naturally Fractured Reservoir Using Seismic Attributes
Authors: Ray A. K. , Dandapani R. , Devulapalli S. , Biswal S.
Published: October 2023

Characterizing the naturally fractured unconventional reservoirs is challenging because of the reservoir complexity and heterogeneity. Delineating Fault-fracture networks through seismically derived discontinuity attributes is an effective way to characterize these fractured reservoirs. As there are multiple discontinuity attributes containing meaningful information about the fault-fracture networks, it is important to integrate these attributes using a sophisticated machine learning technique for enhanced delineation of these fault-fracture networks. Self-Organizing Map (SOM), the latest and robust unsupervised classification technique, can extract the integrated information of these anomalous features from multiple seismic attributes.

Automated clustering algorithms fall into two categories – supervised and unsupervised algorithms. Unsupervised machine learning algorithms are purely data-driven and help in recognizing and classifying the patterns from a dataset without any prior information. Posteriori information such as well data, is integrated into the results for recognizing the facies classification and calibrating the interpretation. Unsupervised learning methods also help to highlight subtle stratigraphic features that might otherwise be unnoticed using conventional analytical methods.

In this study, we adopted a recent unsupervised classification technique called SOM. The technique has been applied successfully to a naturally fractured reservoir in an Onland field, in India. The objective of the study was to extract the subtle faults and fracture network information from the seismic-based attributes in order to characterize the naturally fractured reservoir. By use of the relevant seismic discontinuity attributes and application of the advanced SOM technique using optimum parameters set, subtle faults/fracture corridors could be mapped effectively using the SOM results. SOM Principal Axis derived from this technique, was a valuable attribute in characterizing the naturally fractured reservoir. This attribute was also a useful input during the Discrete Fracture Network (DFN) modeling stage, in guiding the natural fracture network propagation.
Smart-Drive Navigation & Emergency Response Solution
Authors: Almasri H. J. , Al-Hosany A. J. , Al Habshi M. H. , Khalil B. M.
Published: October 2023

The Smart-Drive Navigation & Emergency Response Solution represents a cutting-edge, customized solution developed internally by our COMPANY's IT and GIS teams. Leveraging the Esri GIS technology suite, including ArcMap Pro, Navigator, Tracker, and Field worker, this solution harnesses the power of advanced sophisticated algorithms to optimize multi-destination routing and conduct advanced routing analysis.

These algorithms consider many parameters, including average speed limits, hazard zones, road conditions, closure times, fenced roads, private roads, vehicle types, user classifications, obstacles, and access locations.

This remarkable solution has emerged as a pivotal tool for optimizing field operations, maximizing resource distribution, enhancing field teams’ mobility, mitigating driving risks, reducing commuting time, and improving emergency response times. In addition to minimizing costs and saving valuable time, it significantly enhances overall Health, Safety, and Environment (HSE) performance and operational efficiency.

Within this manuscript, we delve into the challenges that were overcome, the innovative solutions implemented, the notable features of the system, and the extensive benefits it provides. Furthermore, we explore the promising prospects that lie ahead for this remarkable system.
Production Optimization with Clamp-On Multiphase Flowmeter
Authors: Black Michael , Heinks Carsten , Cramer Ron
Published: October 2023

In order to enable real-time production optimization and reservoir performance of a given oil asset it is necessary to establish continuous production measurement of the producing wells. A clamp-on Electromagnetic Acoustic Transducer (EMAT) multiphase metering system has been developed that can be rapidly installed on all, or some of the production flow lines of new wells or retrofitted to existing wells with zero intervention. The clamp-on aspect of this non-radioactive EMAT measurement approach simplifies measurement across multiple wells within a field or reservoir. Real-time continuous field measurement results from producing wells are presented, and the associated opportunities for automation and production optimization also are explored.

The work flow that was used to configure the meter prior to installation to the line also is described. This process included empirical and physics-based flow analysis of reported well conditions based on pipe geometry, production data and PVT information. In preparation for each well, simulations were performed using the Taitel and Dukler model to predict the flow regime [1].

Following this the EMAT flowmeter was brought to multiple well sites and installed on to producing flowlines downstream of the well head surface choke where measurements were taken. Results obtained were compared against the expected flow conditions obtained from references such as test separators.

It is possible with the clamp-on meter to monitor the flow regime within the pipe by monitoring diagnostic parameters, which are compared to the predicted behavior of each of the wells. Real time flow regime monitoring can be very useful for optimization purposes and is usually not achieved using traditional well testing techniques.

The EMAT measurement technique is a novel approach for multiphase clamp-on well production measurement: the field measurement results are presented for the first time in this paper. The rapid, non-intrusive and cost-effective deployment of this EMAT multiphase flow measurement device presents potential for significant well/reservoir production and HS&E improvements in the area of oilfield surveillance and production optimization.
Strengthening Digital Transformation of Rigless Well Intervention Through ROSE Platform, Driven by Well-Planned Strategy and Business Objective Alignment
Authors: Maher Manar , Syafruddin Muhammad , Reddicharla Nagaraju , Subaihi Maad , Albadi Mohamed , Desouky Tarek , Ahmad Zeeshan
Published: October 2023

Rigless well work intervention is at the forefront of field production cycle that integrates production optimization, reservoir monitoring plan (RMP), well maintenance, and well integrity. It is imperative that the oilfield provides efficient rig less planning, monitoring, and optimization, despite of dynamic challenges of field operation, that non only ease the business workflow but also attract opportunities, improve resources utilization, and optimize operational cost. To this end, the integrated online platform of rigless operation schedule entry (ROSE) provides a collaborative access for all stakeholder to streamline planning and scheduling of rigless activities and resources.

Rigless well planning was traditionally conducted in manual basis using an excel spreadsheet. Without data integration, well input was sourced in scattered from different data bases that requires significant man hours to develop the plan. Furthermore, an extra effort is exerted to adjust or revise the plan and not easy for tracking and optimization. Progress or actual reports were communicated in email or shared folder to concerned stakeholders i.e., Development, Operation, and Well Integrity that is deemed not practical. ROSE is developed as digital solution where all rigless activities and resources are synchronized in one platform, provide all stakeholders an easy access and data extracting. ROSE also facilitates an automated well recommendation as a feed of rigless scheduling from RMP automation, PIES business plan, and well integrity workload.

The integrated online platform of rigless operation schedule entry (ROSE) has been built to integrate rigless well plan, provides collaborative input and enhance rigless packages utilization. The platform provides user friendly features to initiate, revise, and optimize the well plan. ROSE proves an improvement of 20% in rigless package utilization by rigless operation clustering that translates to potential cost saving $1.2MM per year for an asset. In addition, it generates an automated report feeding to several business performance KPIs. The platform streamlines communication workflow which reduces emails and reminders and saves thousands of manhours spent in manual scheduling that otherwise can be allocated to other essential well operations.

Development of ROSE is driven by the philosophy of do more with less with data integration and collaborative work at the core of its development. The platform is maintained simple with an easy interface for user to develop rigless well work plan. Yet, the system provides high visibility of overall rigless plan throughout the year and support realization of well operational business plan.
Physics-Augmented Data Driven Method to Detect and Quantify the Impact of Well Interference
Authors: Sinha Utkarsh , Chauhan Prithvi Singh , Zalavadia Hardikkumar , Sabharwal Varad , Sankaran Sathish , Chen Clark
Published: October 2023

In unconventional reservoirs, well interference caused by hydraulic fracturing of a child well can significantly affect productivity of the parent well, leading to prolonged shut-ins and increased operational costs. Therefore, a reliable approach is needed to detect well interference, quantify impact, and forecast the resulting production profile. This study proposes a physics-based data-driven method for identifying well interference events and quantifying their effects on subsequent well production using minimal and easily accessible input data.

In this work, we suggest a workflow for detecting well interference and quantifying its impact based on a transient well performance (TWP) methodology. The main steps in the workflow include computing the dynamic drainage volume (DDV) using the diffusive time of flight (DTOF) method, history matching on pressure and rates, calculating transient productivity index (PI), detecting breakpoints in PI evolution, and fitting a multi-segment TWP model to forecast production rates. We also implement physically consistent validation criteria based on directional variations in water-cut and pressure to determine if the anomaly is the result of well interference. The method is scalable and is run on a routine basis (daily) to pick up new events and automatically update the forecast for all wells in the field. The improved forecast is a result of two major effects – first, accounting for pressure variations as part of the TWP method that normalizes operational variations; and second, the ability to account for interference and extraneous influence to recalibrate well performance.

We verified and validated the proposed method on multiple US onshore fields with extremely high accuracy. Both before and after well interference, the production forecast results were compared with actual production rates, and the results were highly accurate. Further, a root cause analysis was performed to find correlations between the interference results and potential driving factors. Our results indicate that not all interference events are detrimental to long term well performance. Some of the results generated by this method could be useful in understanding the mechanisms to predict or control future interference events.

This study offers a systematic and computationally robust approach to identifying well interference events and quantifying their effects on subsequent well production using minimal and easily accessible input data. The proposed method provides a quick, distinct, and understandable physics-based data-driven approach that can be used as part of closed-loop reservoir management to scale up to the entire field.
Suitability of Various Loads and Structural Response Methods for Fatigue Analysis: A Comparative Study in Arabian Gulf Region
Authors: Uthamanthil N. K. , Thomas A. P.
Published: October 2023

In shallow and intermediate seas, jackets and towers often support offshore facilities like oil and gas platforms and wind turbine foundations. Additionally, these formations may exist in deeper seas. They are tubular-element lattice structures with vertical or slanting legs and tubular bracing. Offshore jackets are susceptible to fatigue due to cyclic wave produced by wave-induced forces and high number of welded tubular connections. These two aspects contribute to the sensitivity to fatigue of offshore lattice structures.

For the successful design of offshore constructions, fatigue damage is a crucial limit state criteria since materials with greater static strength must now be used. Historically, the aviation sector was the first to use fatigue as a design criterion, followed by nuclear, steel, offshore, and marine industries. In the latter case, the fatigue limit state (FLS) must be established explicitly due to the use of higher strength steels in the design. Typically, S-N data are derived from laboratory studies, which serve as the foundation for fatigue failure design requirements.

The concept selection step for field development necessitates the consideration of a thorough approach to assess the historical and prospective fatigue damage of an existing Offshore jacket structure. It is imperative to ensure that the chosen procedure is highly rigorous due to the significant financial ramifications involved.
Successful Implementation of a Novel Low-Viscosity Retarded Acid System in a Depleted Reservoir – Case History from Mexico
Authors: Lugo Ramiro , Guillot Guillermo , Mercado Modesto , Vasquez Julio , Colon Alberto
Published: October 2023

This paper describes the planning and execution of a challenging well stimulation operation on a well in the southeast Mexico basin. The job was successfully executed despite complex conditions and the involvement of multiple services, including Coiled Tubing (CT), downhole tools, and fluid services used in efforts to solve a limited wellbore–reservoir communication. The stimulation design included first-time operator implementation of a chemically retarded acid system proving that depth of penetration can be maximized in an open hole long interval carbonate reservoir using a Hydrochloric Acid (HCl) blend with low viscosity and a nonpolymeric water soluble modifying agent.

1 ½ in CT with a milling tool was used initially in an attempt to overcome mechanical resistance while re-entering the well completion. Subsequent trials to spot and inject fluids with the CT resulted in some success from the first acidizing treatments. The main challenge included designing and implementing a customized matrix acidizing intervention to limit the Near-Wellbore (NWB) spending and opening a pathway in a slotted liner completion with a severe mechanical obstruction.

Placement of the reactive stimulation fluids required the application of proper techniques to reduce initial pumping pressure and establishing communication into a carbonate formation. Despite bottom-hole conditions restricting reservoir injection, a comprehensive analysis and operational preparation played a major role in successfully executing this acidizing intervention. Stimulation resulted in a five-fold production increase with a stable post-stimulation wellhead pressure indicating improved wellbore-reservoir communication.

Results demonstrated significant advantages to acid stimulation jobs that include chemically retarded HCl without gelling agents or emulsifiers. These improvements include: (a) reduced risks associated with formation damage or HSE concerns if applying only gelled or diesel emulsified acids blends; (b) deployability in high treating pressure wells where pipe friction losses are a major consideration; and (c) achieving maximum acid retardation and deep penetration.

This achievement highlights the potential of conducting successful stimulation jobs where an acidizing solution may not normally be the first option in wells with challenging downhole environments restricted to flow.
A Methodology to Evaluate Video Analytics for Drilling Safety Operation Using Machine Learning
Authors: Alkaabi Sultan , Al Azri Ahmed , Al Zakwani Saud , Al Tamimi Fadhil
Published: October 2023

In Petroleum Development Oman (PDO) mission that committed to empower employees with the needed capabilities and fuel innovation, efficiency and more importantly achieve and sustain a 100% Health, Safety and Environment (HSE), by transforming the way of handling HSE events by moving from reactive to proactive approach. Drilling operations represent a challenging environment due to human factors that prone focusing on operations mainly instead of safety of Personnel Protective Equipment (PPE). Surveillance cameras are installed in various locations in rig floor and contribute to security and safety. However, the current methods of video analytic in floor rigs are weak in the long-term sequence of nodes with missing and abnormal error value such nighttime, low illumination which causes poor images. In a proof-of-concept exercise, PDO has been provided the AI Solution to overcome all above limitation to develop AI Models based on drilling operation on rig floor. Consequently, this paper presents machine learning pipeline that is validated and evaluated the vendors Video AI detection of HSE violations of PPE and restricted zone access on the rig floor that shared video dataset. The pipeline can be described in two parts. Due to the complexity of the use case that usually difficult to be managed in-house, we propose a method to bring different algorithms solutions from different vendors where the evaluation is managed in-house. In this, we present a framework for video analytic evaluating safety operation drilling in floor rigs. This framework contains the data of video source that collected, annotations guidelines to support necessary data quantities for the best machine learning approaches, performance metrics, and tools that containing scoring baseline models to be able compute amazing performance output regarding annotated ground truth data. The benefit of this study was to address some challenges of video object analytic and tracking beyond evaluation framework that enables a significant comparison of Machine learning models, provides AI vendors with sufficient data for the exploration the automatic modeling approaches, encourages the incorporation evaluation the techniques with process development, and contributes valuable oil and gas drilling that will demonstrate very useful to Computer Vision (CV) research for next years.