bluuebunny/crossref_metadata_2025 huggingface dataset:
Novel Redevelopment and Economically Promising Approach Doubled the Recovery for a Carbonate Reservoir Unit in Abu Dhabi Field
Authors: Daoud Ahmed M. , Alnaqbi Jawaher M. , Farnetano Ruben P.
Published: February 2022

Objectives/Scope

One of the reservoir units producing from a carbonate reservoir in Abu Dhabi field since 1980 is characterized by having relatively good rock quality to the South with deterioration in rock quality towards North. Inverted nine spot gas injection pattern started for this unit since 1992. Despite all the efforts to improve the recovery from this reservoir unit, still the recovery factor after 40 years of production did not exceed 15 %. This is in addition to the inability of the unit to sustain its production target.

Methods, Procedures, Process

A novel mixed pattern gas and water injection scheme proposed to improve this reservoir unit recovery. First, replace the existing gas injectors by water and add new water injectors in good-quality area to ensure good water injectivity. Second, reduce gas injection or add new gas injectors if needed in the poor-quality area to keep a minimum VRR of one splitting equally between water and gas injection. We developed a novel line drive pattern approach for locating the new water and gas injectors which we call it "Produce Shallow and Inject Water Deep (PSIWD)" for water injectors and "Produce Deep and Inject Gas Shallow (PDIGS)" for gas injectors. All the injectors are horizontal to imitate bottom aquifer for PSIWD in the good-quality area and gas cap for PDIGS in the poor area. Similarly, all the producers are horizontal located at the top of the reservoir in the good-quality area and at the bottom in the poor-quality area to reduce the water and gas early breakthrough.

Results, Observations, Conclusions

This approach simulated on a full field scale and proved its efficiency in increasing the recovery factor to 40 % and maintaining longer plateau for 18 years. On top of this, it is economically promising by reducing the OPEX for gas injection to 1.2 Billion USD savings that can reach to 2.4 Billion USD savings in the next 30 years with the application of full water injection (PSIWD) in both good and poor-quality areas.

Novel/Additive Information

Unlike the conventional line drive pattern with injecting and producing within the oil column, our proposed mixed line drive pattern water and gas injection with the application of PSIWD in the good-quality area and PDIGS in the poor-quality area has tendency to reduce the gas and water breakthrough thus ensure better sweep efficiency and higher pressure support. On top of this, the proposed development approach shows 40 % reduction in the cost per barrel compared to the current development approach due mainly to the OPEX reduction for the gas injection and the incremental increase in recovery.
AI-Enabled, Automated Digital Dull Bit Analysis - Field Experience
Authors: Alalsayednassir Alawi , Berger Per Erik , Bergfloedt Charlotte , Schmitz Ronald , Schmitz Ryan , Emery Séan
Published: February 2022

Background

Digitization and automation have been areas of increasing focus in the drilling industry in recent years. One critical area of drilling operations that has been largely overlooked in the drive to digitization is the assessment of drill bit wear and damage. The International Association of Drilling Contractors (IADC) drill bit dull grading standard is the current industry reference to document the condition of a dull drill bit. Since these protocols rely on human interaction and judgement, the resulting data is limited in terms of its accuracy, its consistency, and its comparability. As a result, the usefulness of this data in improving how bits are designed and operated is also limited.

This paper describes an experience of a new system, which involves scanning a drill bit, and digitally analysing the results, thereby overcoming the limitations of the current protocols. The implementation of the drill bit scanner and dull bit grading software services will contribute greatly to improve the inspection, and classification of drill bits. Furthermore, it will enable to monitor drill bit performance, and optimize drilling processes by utilizing the data provided by the system.

The system described incorporates the automated generation of a digital three-dimensional visualization of a dull bit, which is then analysed digitally to assess wear and damage, on an individual cutter basis, as well as on an overall bit basis. Since the process is automated and digital in nature, the uncertainties related to human interaction and judgement in the process typically used today are eliminated. This data can then be used to identify drilling dysfunctions, and modify drilling procedures accordingly to optimize performance, as well as to identify potential improvements in drill bit design.

Examples of digital dull bit analyses demonstrate that the bit wear data obtained from the system is much more detailed, more accurate, more consistent, and more comparable than the methods employed today. The resulting data is also much more suited to analytics, as well as other types of analyses, with a view to improving bit designs, identifying drilling dysfunctions causing bit damage, and optimizing drilling operating parameters to improve performance.
Synergistic Technique Enables Top-Drive Cement Head and Casing Running Tool Adapter to Improve Zonal Isolation with Safety and Efficiency in Colombia
Authors: Castro Fabian , Arroyave Juan Manuel , Roldan Sergio , Vela Jose David , Garcia Nelson Eduardo , Lopez Alexander , Fiaga Maria Anayibe
Published: February 2022

Casing rotation is a mechanical aid that improves fluids displacement efficiency and helps achieve zonal isolation. A Colombian oil company faced its biggest challenge to successfully place cement across zones with washouts, rate restrictions, and difficult mud removal.

This paper describes the deployment of a rotating cement head for cementing services on a land operation in Colombia, Ecopetrol S.A. has supported and leveraged the deployment of this technology since 2018. The Casing Running Tool (CRT) Adapter provided an enhanced system to reduce stuck pipe risks and decrease rig up time.

The main solution selected to enhance results was implementing casing rotation; nevertheless, execution had to be completed safely and efficiently.

Top-drive cement heads are commonly used in offshore operations. In Colombia, the use of a top-drive cement head was targeted as a safe solution to rotate intermediate and production casings in land operations. This method would allow for rig up, pressure test, and execution of the cement job (including rotation throughout the entirety of the job) without having to break connections or shutdown operations. The main component of the system is the cement head itself, but it was necessary to also incorporate a triple water bushing that serves to connect the cement head with casing and cementing plugs for the specified casing size. The system was enhanced by incorporating an adapter that allows connecting the assembly directly to CRT.

This configuration enabled us to complete cementing without any connection make-ups during job, which reduced personnel risk and saved any flat time.

During the installation process in prior operations, it was necessary to disconnect and rack back the casing running tool and then connect the cement head to the top drive. In some cases, the overall time to perform these actions was about 1 hour and 30 minutes. On certain wells this additional time could increase the risk of stuck pipe and prevent our ability to rotate the casing during cementing. The system has been improved by adding a CRT adapter that joins the cement head to the top drive without disconnecting the CRT.

This new system helps mitigate stuck pipe risks by reducing connection time to as little as 10 minutes while safely enabling casing rotation to improve cement isolation.

This configuration enables casing rotation during cementing in wells with high torque requirements and stuck pipe risks while improving annular cement placement. The system makes the operation safer and more efficient.
Creative Engineering Solutions Accelerating Delivery Across Onshore Horizontal Oil Producers Wells by 20% in the Middle East
Authors: Almuallim Mustafa , Silva Paul , Al Shaikh Jaffar
Published: February 2022

A study of detailed engineering solutions development and the analysis are described in this paper to optimize drilling and flat time operations across onshore Horizontal Oil Producers in the Middle East.

This approach discusses detailed engineering analysis conducted to enhance rate of penetration (ROP) and flat time operation. ROP of each section was increased by optimizing bit selection based on bit records and lithology analysis. Then, a road map was constructed based on dynamic analysis involving shocks and vibration, stick and slip and actual mechanical specific energy output at the bit. Flat time was minimized thru the implementation of creative initiatives including setting casing on bottom to decrease WOC time. Additionally, BHA components across vertical sections were standardized to minimize handling time. Finally, excessive time to picking up and lay down additional 5-in. pipes historically used to drill curved section and run liner was eliminated thru utilization of 4-in. DP across curved and lateral sections.

During the drilling campaign of over 30 wells, all engineering solutions described in this paper were successfully implemented and resulted in 20% optimization of overall well delivery time across onshore Horizontal Oil Producers in the Middle East. Conductor casing was set on bottom eliminating time to wait on cement (WOC), BHA configurations of drill collars, HWDPs, reamers and jar where standardized resulting in 25% optimization in flat time associated with BHA and pips handling at top vertical sections. Additionally, 5-in. pipes were eliminated through proper utilization of 5-in. HWDP to drill top holes and 4-in. pipe to drill curved and horizontal sections saving over 2 days of well time. Drilling performance was improved by over 20% after the implementation and follow up on road maps.

This study provides practical and creative solutions that can be easily replicated elsewhere to optimize well construction time. Also, this paper discusses novel solutions associated with buckling and TnD analysis for casing on bottom and drilling curved sections with 4-in DP.
Influence of Temperature Profile Modelling on the Accuracy of Hydraulic Parameters Estimation Effect of Temperature Profile Change Due to Continuous Drillstring Rotation
Authors: Zherelyev Alexandr , Molster Jon Bjorn
Published: February 2022

ERD wells are widely used by operators in the MENA region to maximize reservoir contact, lower cost per barrel accessed, and to be able to access far away drill targets from fewer drill centers (wellhead platforms, islands, drill pads). ERD wells and associated required technological well construction approaches by nature are typically non-standard. ERD well construction require very exact and detailed engineering analysis and methodologies to be applied in order to develop suitable and accurate drilling designs that closely matches to the actual conditions. During drilling of ERD wells, a ME operator observed that the static geothermal gradient and subsequent modelling of dynamic flow temperature did not match actual downhole temperatures, hence modifications were required to the temperature profile to match the simulation of OBM drilling fluid ECD (Equivalent Circulating Density) to actual ECD measurements from the ECD pressure sub in the BHA. This temperature effect arises from the several factors, mainly in the sub-surface environment. The resulting mud temperature is significantly higher than static temperature and this has a high impact on mud rheology, resulting pressure losses and hole cleaning. Failure to model correctly can result in mud losses or loss of horizontal section because the ECD gets above formation fracture gradient, to low flowrates for effective hole cleaning due to excessive standpipe pressures, and other problems. This paper presents how hydraulics were modelled to match actual data (rheology, ECD, SPP, BHA, Flowrate, ROP, RPM etc) in one of the longest ERD wells ever drilled.

In response to the challenges faced by a ME operator to improve the quality of hydraulic modelling and drilling design, a global Oil and Gas service company and a ME operator jointly explored the approaches for simulating Effective Temperature Profile on the giant offshore oil field, calibrated and verified it along hole with application for providing accurate estimation of hydraulic parameters. The workflow starts from analysis of actual temperature readings in upper sections of the well then uses it for simulating of Effective Temperature Profile in the reservoir section. Then simulated Effective Temperature Profile is imported to the simulation tool for proper drilling design.
Corporate Social Responsibility CSR and Citizenship Engagement
Authors: Dabbous Mohammed , Yateem Karam , Khanferi Mohammed
Published: February 2022

The main objective of the paper is to outline a well-established CSR program and covers a number of special social engagement events throughout the years covering diverse demographics in collaboration with multiple organizations and corporate entities of technical/professional societies and academia to effectively collaborate and conduct major activities such as:

Community awareness aiming to engage the local communities and promote the awareness of environmental conservation. Safety and environmental awareness for school students to learn tips about protecting the environment and home fire safety. Blood donation campaigns.

This paper associates the development and delivery of various programs toward serving the local content and emphasis upon the science, technology and engineering. The program is a series of hands-on workshops, 2 days per week in three tracks: science, electronics and robotics. It aims to attract more females participating in STEM fields (science, technology, engineering and math) by training teachers, engaging the students, and connecting them with female role models working in STEM fields.

The successful implementation of the subject programs has granted a top corporate performance of corporate social responsibilities. The program firmly believes in educating the local communities through workshops, campaigns, trips and awareness sessions. A number of sessions have been arranged with great participation and enthusiasm. Furthermore, professionals facilitated the delivery of petroleum engineering modules in participation of the government's gifted students’ program. This participation serves the role of attracting high achieving students to join the energy industry by showing them the exciting career opportunities the industry has to offer. Finally, blood donations have contributed to the health of the community as part of HSSE and CSR program.

The paper will also touch upon the initiation of the internal guidelines for handling the social program including the required themes, Health, Safety and Environment (HSE) and related topics, as well as the process of coordinating such endeavors.
Longest 9 5/8" Casing Cementing in ERD Well, A Worldwide-Record
Authors: Alzaki A. , S. Al-Shammari Nawaf , Masoud Zuleta Rodny , De la Cruz Sasso Alejandro
Published: February 2022

The efficient placement of cement as a verified barrier above a distinct permeable zone in any oil and gas well is a constant challenge faced by the industry. Absence of isolation behind the casing represents a deficiency to the required well integrity barriers. A compromised well barrier may result in casing corrosion, leaks, and eventually sustained casing pressure which might lead the loss of the asset and/or endanger the safety or workers and/or the environment.

Ultimately, a compromised barrier implies compromised well integrity. Fluid displacement in ERD wells is different from conventional wells and the job conditions pose additional challenges. To ensure adequate cement placement in this ultra-ERD well, several challenges had to be addressed. Hence, an optimized cement placement method that focused on ECD management to prevent induced loss circulation included maintaining fluids displacement regimes, fluid density, and hydraulic friction hierarchy. Moreover, casing centralization was imperative. Limiting casing string movement once the string deployed successfully to bottom equally added to the challenge.

A system's approach was utilized to achieve the level of optimization desired. Slurry rheology and fluid loss control were adjusted. A pumping schedulethat ensured that optimum displacement efficiencies were achieved in line with the designed rheology was used. The impact of pump rates on downhole ECD regimes were equally evaluated and confirmed to be fit-for-purpose. Mud conditioning prior to the cement displacement and spacer wettability were also of paramount importance. A centralizer spacing resulting in >70% stand-off was utilized. These optimized practices represented the results of 3D modeling used to understand the fluid dynamics, and its distribution under the influence of a horizontal static pipe. This work also presented a comprehensive sensitivity analysis not only on the effects of thermal thinning on fluid rheology, but also on gravitational forces acting on the fluids in an ERD well. After execution, a combination of cement bond logs, ultrasonic measurements, and advanced interpretation techniques were used to evaluate the cement bond quality. The logs showed an improved cement bonding with minimal to no channeling, and excellent radial cement coverage.

As global hydrocarbon resources become harder to reach, ERD wells maybe required to access such subsurface targets. Adequate cementing well integrity is crucial to assuring the long-term integrity of such wells for the economic life of the assets. The practices implemented in this case history will contribute to expanding the tools and techniques available to engineers to achieving excellent barrier isolation in such wells.
Multi-Scale Karstic Reservoir Characterization: An Innovative Approach to Improve Reservoir Model Predictions and Decision Making
Authors: Haddad Antoine , Lathion Rodolphe , Courgeon Simon , Fabre Gilles , Martinuzzi Vincent , Pedraza Sergio , Hauvette Louis , Games Federico
Published: February 2022

This study consists of an innovative multi-disciplinary approach (combining borehole imagery, core data, 3D seismic and field production) which aims at better characterizing and representing karstic features in a dual porosity/permeability simulation model and improving the associated reservoir model predictions in the context of a carbonated reservoir characterization.

The applied methodology can be described as follow:

Identification and picking of karstification features on bore-hole imagery (GeologTM software) Deterministic picking of karstic features as geobodies on the 3D seismic (enhanced similarity volume (PaleoscanTM software) Integrated implementation of the karstification features into the geological model using advanced geostastical methods (Multi-Points Simulation, PetrelTM software) Implementation of the resulting enhanced reservoir properties during dynamic simulations and history matching (dual porosity/permeability medium, tNavigatorTM software).

After their deposition, carbonate reservoir series are affected by intense karstification during a prolonged period of subaerial exposure. They are consequently marked by widespread erosion; dissolution and collapsing features (e.g., solution cavities, solution-enhanced fractures and brecciated intervals) which were first recognized and picked on the borehole imagery. Typical elongated and dendritical karstic features were then identified through advanced 3D seismic attributes and then deterministically picked as geobodies. This picking was performed using advanced similarity seismic volume, at high resolution, to capture vertical heterogeneities in the karstified interval(s) of the reservoir. Then, Seismic extracted geobodies were implemented as key drivers for reservoir properties into the geological model. Since every brecciated zone on the borehole image could not be captured during the seismic picking (either due to resolution, and/or to low seismic quality zone), an advanced Multi-Points simulation was designed and implemented using the "geobody" property as a "training image" (primary constrain). This method reproduces the characteristics of geobodies, such as trends, orientation, shape, and dimensions. This method filled the resolution gap between seismic image and logs and transferred the multi-scale observations into the geocellular model.

The karst-related dynamic properties obtained through this advanced modelling workflow were then refined during history matching and considered as the main driver for variations in well productivity indexes. This tailor-made approach critically impacts redevelopment opportunities that will ultimately safeguard and increase hydrocarbon reserves.
Automatic Production Rate Estimation Workflow Considering the Reservoir Flow Regime - Kuwait Integrated Digital Oilfield
Authors: Al-Salali Yousef Zaid , Al-Awadhi Mansour , Hajjeyah Abrar , Al-Shuaib Muna , Al-Saleh Alaa , Useche Marcos , Vargas Carlos , Saxena Aditya , Idele Osaretin Greg
Published: February 2022

This paper presents an automated workflow that can estimate the oil and gas rates of a well, with the high frequency data, distinguishing the behavior of the reservoir under transient flow and pseudo steady state flow conditions.

The new approach matches the wellhead pressure of a well model with the current value reported by a SCADA system, by adjusting the bottomhole pressure. For transient flow, it considers the response of the inflow performance relationship as a function of time. For pseudo steady state flow, it considers the declination of the reservoir pressure. The estimation of the production rate is carried out every 15 minutes, and the total daily produced volume is calculated based on the effective flowing time.

To evaluate the accuracy of the new well rate estimation workflow, the output of the workflow is evaluated using two different criteria. Initially, the estimated oil and gas productions are compared with data from a real well test that is used as a quality control point. Secondly, considering that the fluid properties remain stable over time (water cut and gas-oil ratio), the critical flow through a choke valve defines a historical production trend that is used to quantify the deviation of the estimated values. As a result of the new workflow application, the difference between the estimated and measured rates decreased from 10% to 3%.

The novelty of the new method is that it reduces the error of the estimated oil and gas production rates using the actual reservoir pressure behavior and provides more precise data for the different reservoir engineering analyzes.
Multiphase Pumping with Progressive Cavity Pumps
Authors: Hester Mike
Published: February 2022

Multiphase fluids are mixtures of oil, water, and gas. Roughly six out of every ten wells contain multiphase fluids with variations in the fluid makeup, rheology, and viscosity. They may also include small amounts of sand, paraffin, hydrates, and drilling cuttings. This necessitates local separation at the well site, which can require a significant footprint of process equipment infrastructure at or near each well site.

Ever since oil production began, produced fluids have been transferred from the well to the storage or processing facility using reservoir pressures. This means the bottom hole pressures needed to be sufficient to not only get the fluid to the surface but also move it some distance on the surface through flow lines. In cases where reservoirs are either low energy or are characterized by rapid pressure depletion curves as is common in a number of unconventional plays, this can be problematic.

In wells that are artificially produced with a down hole pump or other artificial lift equipment the pump must have sufficient pressure capability to bring the fluids to the surface and then move them some distance on the surface through a flow line. Additional pressure may also be required for the separation equipment at the end of the flow line.
Improved Clean Water Identification & Capturing in High Complex Environment
Authors: Alghanim Rayan , Fateh Ahmed , Mattar Tariq , Gonzalez-Gallardo Carlos
Published: February 2022

A methodology to determine water contamination levels prior sampling to guarantee the capture of representative water samples, as its highly crucial for understanding saturation profile, reservoir reserves & field development planning.

The presence of low salinity mud while trying to sample low salinity water adds further challenges in acquiring a clean sample. Especially, that the resistivity measurement sometimes won't have a resistivity contrast. Nevertheless, the conventional optical density measurement won't be able to differentiate the two water types.

Applying power law model and utilization of resistivity/conductivity and density measurements to quantify contamination levels as the fluid property in miscible filtrate & formation water will match such transition profile. Since both water base mud filtrate (WBMf) & formation water exhibit the same optical spectroscopy response, it will be quite challenging to differentiate between them. Hence, the above method is used to quantify accurate contamination. The pH measurement was also used to monitor rate of change & stabilization across pump out station whenever there's no contrast in salinities between WBMf & formation water.

The contamination calculations process can be divided into four steps: Firstly, exponent selection for the power law which depends on the inlet selection, either radial probe or single probe. Secondly, determination of filtrate properties (initial end point). Third, flow regime identification diagnostics after power law fitting. Fourth, end point extrapolation.

The resistivity/conductivity, density and pH measurements were utilized during down hole fluid analysis of water stations to evaluate the contamination levels using the power law model in a shallow carbonate environment. The model was tried for multiple inlets radial probe & single probe using different power law exponents. The results were consistent and determined the right timings to sample clean water bottles with minimum contamination levels to be analyzed at the lab. Hence, providing accurate geochemical analysis for the reservoir's field development planning and optimizing station time and avoiding unnecessary pump out in real time which saves time and cost.
Quantify and Commit to Sustainability
Authors: Srinivasan Hariharan , Menon Vimal , Al Hamdan Mohammed , George Lege , Al-Saleh Ahmid , Ujainia Vishal
Published: February 2022

Greenhouse gas (GHG) emission is a worldwide concern and emissions with fossil fuel are increasingly questioned. As Schlumberger, we have committed ourselves in Paris agreement for setting science-based targets to reduce our greenhouse gas (GHG) emissions on all the 3 scopes of carbon emissions. This is also a part of Schlumberger's vision towards Net Zero emissions which will help in the transition to a sustainable future.

Our CEO Olivier Le Peuch said, "Schlumberger seeks to lead positive, measurable changes in GHG emissions within the industry to help reduce climate change". Energy industry has a key role to play in reducing the effects of climate change. Schlumberger takes pride in technology leadership paired with social and environmental responsibility. Today along with Schlumberger, world's iconic companies like Microsoft, Shell and BP have also committed for Carbon reduction, Carbon negative and Net Zero. Schlumberger is proud to say that it is the first Company in Upstream Exploration & Production Services to set an Ambition to achieve Net zero by the year 2050. In June 2021, we announced that this reduction will be achieved by reducing 30% on Scope 1 and 2 by 2025, 50% on Scope 1 and 2; 30% in Scope 3 by 2030 and Net Zero by 2050. The reduction of carbon emissions starts with the quantification of carbon emissions and this project is in line with the company's commitment to Net Zero. The project focuses on Scope 3 Emissions which has never been done in a systematic way in the past.

Middle East Center of Reliability and Efficiency (MCRE) in Dammam is one of the pioneers to kick start this quantification of GHG emissions to show that we can make a significant impact towards setting this target. For this to happen, we quantified emissions for specific Technologies related to Scope 3 to benchmark our baselines so that we can put a plan to reduce them. This project established Carbon footprint as an Assessment tool to Simulate Emissions. The tool will provide a competitive advantage in terms of Sustainable Development for Schlumberger and other Oil & Gas industries worldwide.
Novel Integrated Behind Casing Opportunity Maturation Workflow
Authors: Razali Nur Farhana Mohd , Ashqar Ayham
Published: February 2022

To appraise remaining behind casing opportunities in brown field after years of production, and depletion of main perforation intervals. Offshore environment is challenging and ensuring the presence of hydrocarbon requires significant investment, which is not always viable due to the economical additional reservoirs margin. A novel multidisciplinary workflow is developed to add assurance in apprising the remaining opportunities within the Idle wells prior to progress towards plug and abandonment.

Limited data availability and economics allowed the development of a workflow to reduce uncertainty and ensure the presence of hydrocarbon when no cased hole saturation logging is justifiable. The workflow starts by relooking into the open hole logs to identify additional or marginal reservoirs. A complication index is assigned to each which refers to the easiness of the planned additional perf and the success ratio based on open hole data. A complete study to nearby wells production and the water oil contact movement is carried out based on the assigned complexity index. Opportunities were then ranked against the economics of additional perforation, cement bond logs were used to identify behind casing channeling especially when a gas or water contact is interpreted.

The workflow which integrates the reservoir static and dynamic sand aligns petrophysics, dynamic model, history match and contact movement is developed to mitigate any behind casing opportunity consequent to no cased hole logging possibility, and to minimize the risk of not encountering hydrocarbon due to the long production. Any misleading allocation, potential risk (sand, wax, gravel pack, other completion accessories), predict future production based on location of new perf, plan for simulation or production enhancement job, remedial job, identify potential fault (unseen) at limited pressure data block, The workflow is proven to be successful to derisk the presence of hydrocarbon and to identify the most promising hydrocarbon bearing formations, with positive results as perforations are carried out where hydrocarbon are flew.

This novel, comprehensive and integrated workflow generated a reliable tool to identify remaining potential trapped behind casing and possible risks of fluid type, current contact, impurities and well completion. The workflow is developed to generalizes the methodology to assess remained hydrocarbon within idle or high water cut wells, with risk reduced because each discipline contributed to the assessment with the potential risk associated with their discipline. Proper plan is together, capturing all possible risks and ensuring capturing the remained hydrocarbon.
Extending the Operational Limits to Target Mega Reach Interventions with Coiled Tubing: A study of the First 40,000 ft Long CT String Deployment Using Uniquely Engineered Energy Transportation Solutions
Authors: Kaul Karan , Dupouy Nicolas , Jimenez Jose , Ottolina Renny
Published: February 2022

The Coiled Tubing (CT) industry has been growing and constantly pushing the boundaries of established operational limits. This is in line with well drilling paradigm shifts in the middle east. The latest well developments in exploration and well construction demand the deployment of new intervention equipment and technologies to cover the full length of the pay zones. Drilling horizontal wells that push length boundaries, requires new engineered transportation solutions and logistics for independently moving, spotting, and operating CT reels with large Outer Diameter (OD) spools and strings to service mega reach reservoirs.

An operator requiring an offshore CT intervention into 40,000 ft deep wells from the artificial islands of the United Arab Emirates (UAE), encountered challenging crane and transportation limitations to lift heavy 2-3/8" CT reel weighing approx. 200,000 lb. This, combined with a desire to improve operational efficiency in moving from well to well and eliminating large mechanical lifts, led to the design of a custom-engineered transportation solution for the large diameter and heavy CT spool.

This resulted in a cost reduction for cranes and avoided previously lengthy operations potentially taking several days to move the limited availability heavy 500T cranes onto and around the island. In addition, equipment rental and associated operating costs of all the service companies involved in the operation were reduced and allowed tighter timelines to be achieved.

Innovative technology application, custom processes, and an engineered analysis of the transportation and operation were combined to provide the operator with a successful solution for CT reel movement from shore to the artificial island along with the operational execution using the same asset.
Real-Time Hybrid Coiled Tubing Services Improved Confidence and Reliability for Delivering a Successful Zonal Isolation Intervention
Authors: Luppina Salvatore , Mangione Alessandro , Imbò Pasquale , Spagnolo Salvatore , Cappuccio Pasquale , Pollio Pasquale , Fortunato Gianluca , Santin Yoanne , Ridenti Manuel , Caldarelli Riccardo
Published: February 2022

The well (Figure 1) of the case study presented in this paper is an oil producer from carbonate reservoir located in Southern Europe.

Reservoir is characterized by a complex fracture network that increases the difficulties of production optimization actions, as for example water shut off interventions.

This well is completed with a 4-1/2" liner extending to a 4-1/2" slotted liner inside a 6" open hole (OH).

During the production time, the Water Cut (WC) has increased steadily finally reaching 94%, preventing the well from producing naturally.

Log acquisition and interpretation, with Production Logging Tool (PLT) and Spectral Noise Logging (SNL), have shown that the water was coming from a fractures network laying behind the liner, to enter the top of the slotted liner despite swellable packers A and B. The lack of accessibility to this fractures network was therefore posing a challenge for an effective placement of a sealant gel.
Computerized Performance Monitoring System for Turboexpander Brake Compressor
Authors: Goryachikh Vadim , Alghamdi Fahad , Takrouni Abdulrahman
Published: February 2022

Extended Abstract

Natural gas liquid (NGL) production facilities, typically, utilize turbo-expander-brake compressor (TE) to generate cold for C2+ separation from the natural gas by isentropic expansion of feed stream and use energy generated by expansion to compress residue gas.

Experience shows that during operational phase TE can exposed to operation outside of design window that may lead to machine integrity loss and consequent impact on production. At the same time, there is a lack of performance indicators that help operator to monitor operating window of the machine and proactively identify performance deterioration.

For instance, TE brake compressor side is always equipped with anti-surge protection system, including surge deviation alarms and trip. However, there is often gap in monitoring deviation from stonewall region. At the same time, in some of the designs (2x50% machines) likelihood of running brake compressor in stonewall is high during one machine trip or train start-up, turndown operating modes.
Enhancing Indoor Air Quality and Tackling COVID - 19 Virus
Authors: Al Awadhi Ibrahim , Sharma Ashok , Karim Twana
Published: February 2022

Objective/Scope

One of the main concerns of Oil & Gas Plants and associated Buildings is how to improve indoor air quality (IAQ) and tackling viruses. IAQ can be affected, or may become under high risk by some of nearby gases, microbial contaminates or energy stressor that affect the HSE condition. This paper presents the main factors that been considered to provide practical solutions to achieve high IAQ and tackling viruses (such as COVID-19).

Methods, Procedures, Process

IAQ refers to the air quality within and around the plants/buildings. IAQ can usually be affected, or may become under high risk by nearby gases, particulates, microbial contaminates or any mass that affect 100% HSE. Inadequate air quality in building will increase the risk and impact on transferring viruses to people (such as COVID and Flue) and equipment performance (such as equipment failure, components corrosion and short circuits on control board). Survey and data was recorded to evaluate air quality performance in atmosphere instead of assuming it. Accordingly, the impact of inadequate IAQ was studied and evaluated.

Results, Observations & Conclusions

The international standard set a good IAQ in respect of gas concentration and human who works inside buildings in a way that less than 50% people should not detect any odor, 25% should not experience discomfort, 10% should not suffer from mucosal irritation and 5% should not experience annoyance. Study concluded that inadequate IAQ inside the building will affect people performance/health and installed equipment performance. In addition, improper HVAC system operation will be become breeding site for odor causing mold and bacteria, specifically on cooling coil. Hence, several technics were studied to improve IAQ, by installing Ultraviolet (UV) light to stop growing bacterial inside the HVAC system, installing chemical filter in air intakes to remove atmospheric dust, gases and bacteria by 100%, upgrading filtration efficiency to MERV-13 or highest achievable to capture at least 75 – 95% of airborne particles between 0.3 and 1.0 micron, increase outdoor air ventilation and temperature/humidity control.

The performance of HVAC system and quality of air inside building were monitored by simulating IAQ based on ISO 16890, filters life cycle, energy consumption, and the results were found 100% satisfactory and provided solutions that are now successfully implemented in all new and some of the existing buildings.

Novel/Additive Information

There are several buildings with similar issues and these approach/technics now being adopted in new constructed/existing buildings to protect human and asset integrity, which will support ADNOC Way by sustaining safe environment operation, lower health risk, reduce of equipment failure, reduce maintenance cost and 100% HSE. There are numbers of occupied buildings across the world were surrounded by aggressive gases/pollution with poor IAQ and above approaches it can be followed to realize larger benefits.
Implementation of Remote Activated Liner Shoe in UAE Onshore Wells - A Case Study
Authors: Elkasrawi Ahmed , Keerthivasan Vijay Kumar , Mehus Cathrine , Abdelghany Moetaz , Gjedrem Bjørnar
Published: February 2022

The liner shoe is a critical component of the lower completion architecture, allowing for auto-filling of the liner and enabling circulation during deployment, followed by closure to provide a closed system. Advancements in completion technologies have resulted in the development of an intelligent electronic liner shoe (ELS) that can be remotely operated without the need for intervention or pumping trigger devices downhole.

The electronic liner shoe suited for deployment on 4½-in. liner was developed based on specific requirements from a major operator in the middle east. The electronic liner shoe was qualified per ISO 14998/API 19AC requirements up to 280°F. Additionally, the electronics module incorporated in the tool was vibration and shock tested at temperature. After an extensive qualification test program and thorough pre-job qualification and planning, candidate wells were chosen for the initial deployment of the ELS in Onshore wells. The ELS was first deployed in November 2020 in the Bab field in UAE.

This paper highlights the excellent deployment performance using ELS for the onshore field development in UAE. This paper also presents the operational considerations for programming the remote activation mechanism, pre-job risk analysis, technology qualification, and post-job lessons from the first installation, resulting in the ELS’ successful deployment in six additional wells in the onshore fields. The paper also shares the unique benefits the ELS provided the operator towards enhancing operational efficiency, as well as reducing risk and costs associated with running liners.
Low Viscosity Polymer Free Acid Retarded System, a Novel Alternative to Emulsified Acid: Successful Application in West Kuwait Field
Authors: Al-Sabea Salem Hamad , Abu-Eida Abdullah , Patra Milan , AlEidi Mohammad Naji , Ambrosi Giuseppe , Khandelwal Nakul , Gaur Rishika , Matar Khaled , Al wazzan Abdulatif , Vasquez Julio
Published: February 2022

Acid systems are widely recognized by the oil and gas industry as an attractive class of fluids for the efficient stimulation of carbonate reservoirs. One of the major challenges in carbonate acidizing treatments is adjusting the convective transport of acid deep into the reservoir while achieving a minimum rock face dissolution. Conventional emulsified acids are hindered by several limitations; low stability at high temperatures, a high viscosity that limits pumping rate due to frictional losses, the potential of formation damage, and the difficulty to achieve homogenous field-scale mixing. This paper highlights the successful application of an engineered low-viscosity retarded acid system without the need for gelation by a polymer or surfactant or emulsification by diesel.

An acid stimulation job using a new innovative retarded acid system has been performed in a West Kuwait field well. The proposed acid system combines the use of a strong mineral acid (i.e. hydrochloric acid "HCl") with a non-damaging retarding agent that allows deeper penetration of the live HCl acid into the formation, resulting in a more effective stimulation treatment. The retardation behavior testing includes dissolution experiments, compatibility testing, coreflood study, and corrosion rate testing (conducted at 200°F).

The on-job implementation included the use of a packer to pinpoint fluid pumping (pre-flush) at the point of interest, followed by the customized novel retarded acid system for improving conductivity at perforations and effective reservoir stimulation. This acid system is characterized by having a low-viscosity and high thermal stability system that can be mixed on the fly. This approach addresses the main challenges of emulsified acid systems and offers a cost-effective solution to cover a wide range of applications in matrix acid stimulation and high-temperature conditions that require a chemically retarded acid system.

The application of this novel acid retarded system is a fit-for-purpose solution to optimize the return on investment by maximizing the well production and extending the lifetime of the treatment effect. This new system also offers excellent scale inhibition and iron control properties which eliminates the need for any acid remedial work, making it an economical approach over other conventional acid systems.

The paper presents results obtained after stimulating the carbonate reservoir and describes the lessons learned from the job planning and execution phases, which can be considered as a best practice for application in similar challenges in other fields. Proper candidate selection, best available placement technique, and lab-tested formulation of novel retarded acid system resulted in achieving 1700 BOPD of oil production (27% higher than expected).
O controle glicêmico em pacientes diabéticos com Covid-19 em uso de Dexametasona
Authors: Navarros Najla Pinheiro , Venzo Marjorie Rafaelly de Paula
Published: February 2022

Objetivo: Revisar na literatura especializada como o gerenciamento adequado do controle glicêmico pode influenciar para melhores desfechos nos pacientes diabéticos com Covid-19 que estão recebendo tratamento com dexametasona. Revisão bibliográfica: A dexametasona demonstrou redução na mortalidade por Covid-19, com uso abrangente na prática médica no período revisado. Entretanto, por se tratar de um glicocorticoide, seu uso induz hiperglicemia importante, principalmente em pacientes previamente já diabéticos ou com predisposição ao seu desenvolvimento. Estados hiperglicêmicos têm sido associados à piores desfechos na doença causada pelo Sars-cov-2. É necessário um controle glicêmico eficiente no manejo dos pacientes com hiperglicemia e o uso de corticosteroides em pacientes diabéticos deve ser cuidadosamente indicado. Considerações finais: A dexametasona mostrou benefícios em pacientes com Covid-19 em uso de oxigenioterapia, entretanto seu uso em pacientes diabéticos pode causar hiperglicemia importante. O melhor controle glicêmico dos pacientes com Covid-19 é associado a melhores desfechos e menor mortalidade, devendo sempre ser considerado indispensável pela equipe assistencial.
Three-dimensional craniofacial changes with maxillary expansion in young adult patients with different craniofacial morphology
Authors: Almaqrami Bushra Sufyan , Ngan Peter , Alhammadi Maged Sultan , Al-Somairi Majedh Abdo Ali , Xiong Hui , Hong H.
Published: February 2022

Objectives:

Skeletally mature patients with transverse deficiency are best treated with surgically assisted rapid palatal expansion (RPE) procedure. Recent studies have shown that microimplant-assisted RPE (MARPE) appliances can be effective in achieving skeletal expansion in young adults. This retrospective study aimed to evaluate the skeletal and dental alveolar changes in response to treatment with MARPE appliances in three types of anteroposterior skeletal malocclusions using cone-beam computed tomography (CBCT) scans.

Material and Methods:

Seventy-eight subjects diagnosed with maxillary transverse deficiency and treated with the MARPE appliance (mean age of 22.9 ± 4.2 years) were divided into skeletal Class I, II, and III malocclusions with 26 subjects in each group. Pre- and post-treatment CBCT scans were used for superimposition to examine the skeletal and dentoalveolar changes following maxillary expansion treatment.

Results:

Significant lateral separation of the maxilla was found at the levels of the nasal floor, interzygomatic bones, and the inferior palatine margin of the alveolar process (P < 0.05) in the whole sample. Most of the sagittal and vertical variables change significantly in the whole sample and each studied group separately. Intergroup comparisons revealed no significant differences among the three skeletal classes except for the left frontozygomatic angle, left maxillary inclination angle, and torque in the first and second premolars. In Class III patients, the maxilla moved forward significantly in most of the cases (eight of 26 cases) (0.88°, P < 0.05) and the mandible moved downward and backward improving the anteroposterior skeletal relationship. Significant differences were also found in the vertical measurements (N-Me, MMP, and MP/SN, P < 0.05) in all three types of anteroposterior malocclusions.

Conclusion:

Maxillary expansion with the MARPE appliance in young adult patients induced different skeletal and dentoalveolar changes in the anteroposterior and vertical dimensions in each skeletal malocclusion with no significant difference among the three skeletal classes.