bluuebunny/crossref_metadata_2025 huggingface dataset:
Buku Ajar Manajemen Kompensasi
Authors: Firdaus Vera , Oetarjo Mas
Published: May 2023

Bismillahirrahmanirrohim. Segala puji hanya bagi Allah SWT semata, shalawat dan salam semoga tercurahkan kepada Rasullullah Muhammad SAW, keluarga, sahabat dan para pengikutnya. Rasa syukur penulis panjatkan kepadaNya, Sang Maha Pemilik Ilmu, atas karunia dan rahmatNya, penulis dapat menyelesaikan buku ajar Manajemen Kompensasi. Buku ajar ini diharapkan memberikan pemahaman kepada mahasiswa yang mengampu mata kuliah manajemen kompensasi, maupun mahasiswa yang sedang menyusun skripsi maupun penulisan ilmiah lainnya tentang kompensasi. Pemahaman akan terminologi dan sistem kompensasi dapat menjadi bahan penelitian binis, baik bagi penulis maupun mahasiswa. dengan mempelajari manajemen kompensasi diharapkan nantinya mahasiwa mampu menerapkan konsep, teknik dn pemikiran logisnya, ke dalam dunia kerja.
PUSAT PERTUMBUHAN EKONOMI DI WILAYAH PESISIR BARAT SELATAN ACEH
Authors: Fakhruddin Fakhruddin , Varlitya Cut Risya , Alemina Ema , Sufirmansyah Sufirmansyah , Iskandar Irham
Published: May 2023

This research aims to identify alternative areas as the new growth pole and formulate a development strategy in the South West region of Aceh. The methods used are Klassen typology, gravity models, and breaking point. The scope of this research covers 7 (seven) districts and 1 (one) city for the period of 2011 to 2016. The entire district and city are assumed to be an economic unit treated as a parent area for all districts/cities. The results showed that, firstly, there could be 2 (two) growth poles if we divided by coastal areas, namely Nagan Raya District for the west coastal region of Aceh and  Southwest Aceh District for the southern coastal region of Aceh.  However, Nagan Raya Regency is the alternative choice for the new growth pole in South West  region of Aceh. Secondly, the improvement of the agricultural, forestry and fishery sectors as well as the development of human resources in accordance with the needs of the labor market is necessary to be able to develop the new center of economic growth.
The Effect Of Original Regional Income And General Allocation Funds On Capital Expenditure of Central Sulawesi Province The Year 2015-2019
Authors: Latif Abdul , Mardiana Andi , Aisyah St.
Published: May 2023

This study mainly aims, first, to find out the significant evidence of the effect of local revenue on capital expenditures in Central Sulawesi Province, Second, to understand the significant evidence of general allocation funds' effect on capital expenditures in Central Sulawesi Province, Third, to analyze the significant evidence of local revenue and general allocation funds simultaneously on capital expenditure in Central Sulawesi Province. The type of research used is quantitative data. Funds used in this research are secondary data provided by the Directorate General of Fiscal Balance (www.djpk.kemenkeu.go.id) by making Central Sulawesi Province which consists of 13 districts and municipality into the area under study. The results showed partial hypothesis testing that, first, Local Own Income (X1) has no significant effect on Capital Expenditures (Y). Second, General Allocation Fund (X2) has no significant effect on Capital Expenditure (Y). Meanwhile, the simultaneous hypothesis testing results show that Local Own Revenue (X1) and General Allocation Fund (X2) have a significant effect on Capital Expenditure (Y). Keywords: Regional Original Income, General Allocation Fund, Capital Expenditure
Study of Response Analysis of Youth Unemployment Rate in Economy Globalization In Asean
Authors: P Riniati M , Yunitasari Duwi , Arishanti Desy
Published: May 2023

Unemployment is a variable of concern to many countries. The unemployment rate has a negative nature on economic growth in a country. So that various policies were formed in an effort to minimize the increase in the number of unemployed. This study focuses on the Youth Unemployment Response to economic globalization in ASEAN by using secondary time series data from 2010 to 2019.In this study, it was found that the economic globalization aspect gave rise to several different responses to Youth Unemployment in ASEAN. Changes in trade globalization for the period one to ten gave rise to a positive response, while in the aspect of financial globalization it was responded negatively by the youth unemployment rate. In the aspect of youth unemployment responsiveness, the variables of financial and trade globalization have contributed greatly to the increase in the number of youth unemployed in ASEAN. This can be a recommendation for the government, especially Indonesia, in boosting young unemployed people to stay in a safe position. But on the other hand, it does not rule out the flow of economy globalization.
The Perception of Trusmi Cirebon Batik Products on The Role of Sharia Banking Micro, Small, and Medium Industry
Authors: Huuruniin Huuruniin , Hasan Asyari
Published: May 2023

The presence of Islamic banks is expected to have an extraordinary impact on the growth of the real sector, especially Micro, Small and Medium Enterprises. This study aims to analyze the Perceptions of Micro, Small, and Medium Enterprises of Trusmi Cirebon Batik Products on the Role of Islamic Banking. This research is descriptive qualitative, a case study of Batik Trusmi Cirebon. The findings of this study, that the perception of Batik Trusmi Cirebon's Micro, Small and Medium Enterprise's home industry on the role of Islamic banking is still very minimal, and product socialization from Islamic banks are still low, so Batik Trusmi Micro, Small and Medium Enterprises are not interested in making loans or financing at banks. Islam. Some of the factors that influence this condition include Islamic banks whose procedures are considered complicated to understand, unfamiliar product terms, uncertainty, and fear of financing in Islamic banks. The mentoring program also really needs to be carried out by Islamic banks. By providing mentoring programs, people will automatically get to know Islamic banks without having to carry out socialization which is sometimes less effective.
Estimating Drilling Emissions Footprint in a Cloud-Based Well-Construction Planning Solution
Authors: Medina Diego , Qi Chaobo , Zhu Lei , Suryadi Hendrik
Published: May 2023

Many operators commit to reducing their operation's carbon dioxide (CO2 emissions. According to McKinsey & Company (2020)(1), well drilling and extraction processes contribute 8% of the Scope 1 emissions in the oil and gas industry. Rig site activities generate one-third of the overall emissions footprint for the well construction process. A well construction process consists of hundreds of activities and tasks ranging from well spud to rig release. Along the way, many different types of equipment are used. To minimize emissions, we need to analyze how the power is used and how it can be saved throughout the well construction process. Selecting lower-carbon energy sources can significantly reduce Scope 1 emissions, but the transition process takes time. The operator and contractor must continually improve their operation's efficiency to reduce emissions.

The emissions footprint model was developed based on CO2 emissions data and power consumption statistics for land rigs. During well planning, the engineer strives to formulate a drilling program considering the anticipated time, cost, and overall emissions objectives. Emissions volumes should be calculated based on the equipment used in each activity. The engineer compares the technologies proposed for the drilling program to determine the optimum equipment solution with the lowest overall environmental impact. The ability to forecast expected emissions for planned wells helps the engineer make technology selections for each drilling plan. With validated models, it's possible to calculate the CO2 released based on the measured drilling parameters and work to reduce it. For sustainability purposes, the engineer must consider the total emissions created by the entire process as an additional performance indicator.

In this paper we describe the integration of emissions footprint modeling into the overall well-planning workflow. We developed the model by measuring actual emissions and power usage of different rig equipment during different drilling activities. This was done by using a cloud-based well-construction planning solution. The workflow was embedded into the overall well design, enabling the engineer to visualize each project's anticipated time, cost, and emission. Energy consumption was correlated using the provided drilling parameters. Therefore, the emission can be successfully predicted for different well-construction scenarios, drilling technology, and related parameters. This new workflow enables the engineer to plan with sustainability objectives and determine the best overall drilling program for each project.
Digital Drilling Solutions Result in an Outstanding Performance in a Critical Well
Authors: Olivares Tulio , Al-Zahrani Walid , Sharma Sunil , Al Matrouk Hala
Published: May 2023

This paper illustrates the methodology and the challenges faced from the planning to execution phases while implementing digital solutions to overcome the drilling operational challenges. In a candidate well, the package with real-time downhole performance measurement (RT-DPM) software, an automated rheometer, and an automatic data graphic visualization interphase, provided visibility into downhole conditions. This was used to predict potential problems and reduce the likelihood of the common issues related to the drilling operation.

The RT-DPM software was successfully implemented in a well to reduce the likelihood of stuck pipe incidents and hole cleaning issues. The implementation has enabled real-time monitoring of annular pressure, equivalent circulating density (ECD), equivalent static density, pipe eccentricity, swab, and surge pressure, allowing optimization of the operation time. The lateral section has been drilled successfully with high overbalance without any operational issues.

While drilling the production section with several operational challenges, such as losses/gains environment, and high overbalanced formation with a high probability of potential differential stuck, the well was completed successfully, maintaining a good hole cleaning at any point in the annular space of a well. The visibility of the downhole parameters enhanced the rate of penetration (ROP) and optimized the drilling time. A wiper trip was eliminated due to the excellent hole cleaning and the minimal cutting bed generated. Planning started taking into consideration the key point, which was identified as: the close contact points of the pipe to take the extra measurements to avoid such differential sticking in a high overbalanced formation.

The overall results were exceptional from the broomstick, showing the parameters were following the ideal trend with no indications of any tight spots. With a steady pick-up weight, slack-off weight, and break-over torque, the hole was identified to be in very good condition. The oil and gas industry is moving to the automation and machine learning methods, and in this paper we will be presenting the methodology and the challenges faced from the planning to execution phases, while implementing automated digital solutions to overcome the drilling operational challenges.
Successful Deployment of Longest 9 5/8 Production Casing Across Highly Deviated ERD Well
Authors: Hashmi Muhammad Asef , Al Suwaidi Muna , Salem Gamal , Nunez Ygnacio , Al Yamani Sultan
Published: May 2023

This subject Well was drilled as water alternative gas injector in Al Nouf field to optimize and support the pressure sustainability of multiple producer wells across reservoir formation based on MRC / ERD approach. The well have high departure so in order to attain the subsurface targets the production casing needs to be extended.

This paper will outline the planning and execution of successfully deployed the longest production casing in ADNOC Onshore well using hydraulically rotating shoe.

Planning of this well commenced by meetings and collaboration with subsurface operation and reservoir team with the common objective of drilling a smooth section of over 16,473ft as tangent with max inclination of 83 deg.

All the associated risks were highlighted and mitigated by proper planning and engineering analysis such as trajectory, additional wipers trips, collision risks, BHA, hydraulics and casing design.

Inhouse research was done to find a quick solution to cater challenge in deploying long production casing down to section TD. A hydraulically operated reamer shoe was then selected to encounter the challenge with some risk mitigation in place.

The 9 5/8" casing was successfully landed at the target depth of 16,473 feet and subsequently cemented. All the efforts of hole cleaning, dedicated wiper trip played important role in deploying long intermediate case to section TD. Utilization of rotating shoe played a significant role in clearing the ledges and tight hole due to challenging formation.

Rotating shoe was the first deployment in the well where it was identified as a challenging well context and had limited regional experienced. Several previous cases casing being held up in the first run. Despite the fact that a wiper trip has smoothened the hole condition, the parameters that were captured during the running.

The detailed analysis and operation feedback from casing running job and subsequent operation will be beneficial to provide other operators in assessing the minimum requirement and suitability of this technology utilization to overcome the drilling challenge.

This technical paper will show the importance of this project, with the lessons learned, challenges and its mitigation explained in this paper will support the idea to plan and drill the pilot hole and data acquisition in re-entry wells efficiently with key cost savings also will lead to many more successful dual casings exits for future wells.

Successful Deployment Of Longest 9 5/8" Production Casing Across Highly Deviated ERD Well
Horizontal Well Design and Completion Optimization in the Greater Burgan Field for Heterogeneous Thin Sands, A Case Study
Authors: Al-Samhan Amina , Jilani Syed Zeeshan , Al-Nemran Shahad , Muhammad Yaser
Published: May 2023

The Greater Burgan field has been on production for over 75 years mainly from the homogenous massive sands of the Burgan clastic sequence. Given the increasing field water cut from these sands, it is now a matter of strategic focus for the asset to target the generally untapped thin, laminated low quality sands to sustain target production. This paper focuses on a case study for a horizontal well design and completion optimization using sector modeling.

An updated dynamic model, covering the area of interest, was developed. This is an extremely important tool to achieve the study objectives. A sector model was cut out from the full field dynamic model. Grid refinement was performed on the sector, in both vertical and horizontal dimensions. Newly drilled wells were used to update the model horizons, petrophysical data from offset wells in the sector, including geosteering data from the pilot hole, were upscaled and properties populated across the model.

The dynamic model calibration was conducted successfully by including all available well events, workovers, production data, static and flowing bottom hole and well head pressures including all other surveillance data from offset wells. To better match the historical field pressure and water-production, sensitivities were conducted to determine the model response to various parameters including the aquifer strength and faults conductivity. Adjustment of the aquifer strength enhanced the field pressure match, invariably improving the calibration of the model.

After model calibration, the horizontal well was implemented in the model, in line with the design scope from the asset. The biggest uncertainty was the oil-water contact (OWC) in the sector near the planned well. Although offset wells gave a reasonable estimate of the OWC, it was used as sensitivity parameter to cover the uncertainty. This was taken forward into the model prediction simulation work. The modeling study provided immense insights into the probable outcomes in terms of actual horizontal well production deliverability. Multiple rate sensitivities were conducted mimicking the different choke sizes which were planned. These were used as a guide for the asset to set reasonable production target rates for the well.

The study also provided a technical justification for completion recommendations and optimization with a view to maximizing the well's production over time. The horizontal well has been drilled, completed, and tested in the field. The production test rates were encouragingly consistent with the model predictions. The workflow methodologies adopted in this work have now been extended to other wells being drilled in the field.
Sensitivity Analysis and Cost Analysis for Casing Designs (Case Study)
Authors: Abbood Husam Raad , Khalil Dr.Ethar , Miftah Karrar Riyad , Khalaf Amgad Hamad , Abdullah Ibrahim Salim , Khudhaier Muhammed Adnan , Jaber Ali Hassan , Hamad Zamzam Neama
Published: May 2023

The oil and gas industry is witnessing an increasing demand for more cost-effective well design and operations. Thus, the scope of the operator company's planned new processing capacity aims to attain a competitive cost and schedule. In this work, slim versus fat casing designs are evaluated in price and technical challenges, including removing rig/skidding, drilling, and ensuring well suspension.

Data from ten (five slim design and five fat design) wells in southern Iraq was quantitatively analyzed. Attaining the project's target requires that the well be drilled as a deviated well (S-type). The analysis includes the cost of CSG, lost circulation, lost curing, lost circulation materials, volume of the cement plugs to cure losses, non-productive time, stuck pipe and differential sticking, and cement bond quality. Moreover, a cost analysis is conducted by considering all of a project's relevant factors—including economic and technical considerations—to ascertain the likelihood of completing the project.

The finding emerged that the amount of lost mud and the average cost of addressing losses were higher in slim than fat designs. The slim design is associated with higher volumes of cement plugs for curing losses than the fat design. As per NPT analysis, the time required to fix losses emanating from slim design was 62% higher than fat design. A critical observation emerged from the study that while differential sticking failed to occur in both designs, stuck pipes happened in some of both designs. The cost analysis of slim and fat designs focused on the cost of drilling, CSG, wellhead, diesel, and fueling is also done. The total cost of the fat design amounted to approximately 53.67%, while the total cost of the slim design was about 46.33%. This made the slim design's cost savings ratio of roughly 7.34%. Meanwhile, given that similar issues may occur in the proposed well design, the following measures have been isolated to help tackle such problems. (1) Optimize mud design to inhibit Tanuma formation Clay swelling issues (2) Reduce OH time to avoid Tanuma's time-dependent clay swelling. (3) Reduce the inclination across Tanuma to 20 degrees.

Finally, this paper describes how two casing designs are successfully engineered and executed and serves as a guide for selecting proper candidates for this design. Also, it is an operational guide for two casing designs, slim and fat, to ensure that these challenging long open holes will be successfully and economically drilled while minimizing risks and ensuring compliance with the well delivery process.
Motor Wired Power Section as a Solution for Efficient Downhole Torque and RPM Transmission in Long Horizontal Well. Case Study, Onshore Abu Dhabi, UAE
Authors: Baruno Agung , Rizky Amin Muhammad
Published: May 2023

Drilling long horizontal wells in mature fields in UAE are common and challenging. Some of the associated challenges are; lateral length, geological complexity and rig capabilities. One of the challenges in this case is to provide high RPM and torque to the bit and not to increase the maximum make up torque for the existing drill pipes. Powered rotary steerable systems (RSS), applied within the optimum drilling environment, can improve rate of penetration (ROP), lower risks, and reduce non-productive time (NPT), which can decrease drilling costs. Using through motor telemetry technology, a wired motor with a hollow rotor and flex shaft, allows a connection between rotary steerable systems (RSS) and logging while drilling (LWD) downhole tools. A conductor passes power and communication through the motor to operate and steer the RSS. It delivers higher rev/min and torque directly to the RSS and bit. Using the motorized RSS not only has improved ROP but has also mitigated stick-slip vibration and reduced NPT. The NPT improvements have been identified in areas, such as slip-stick vibration, drill string failures, drill string torque variations and rig equipment failures. To run the Motorized RSS on the UAE oil and gas fields the early planning and risk assessment have been conducted. Experience across the worldwide Halliburton locations, both on and offshore, have been presented to show the benefits of Motorized RSS. With improved performance as a result of increased torque and bit speed, and reduction of the stick-slip vibrations, this motor-driven RSS has delivered superior performance and improved ROP in challenging medium and hard formations. At least two horizontal wells with lateral exposure more than 8400 ft was completed shoe-to-shoe with outstanding average ROP using wired power section. It helps to exceed benchmarks by bringing greater horsepower to the rock destruction process with longer runs and higher ROPs. Implementation of wired power section technology for RSS tools will reduce failure risks either for Haliburton either for Customer rig equipment and allows to extend the lateral section footage to develop targets which was unable to hit before. The technology gives opportunity to use the existing capabilities and reduces costs for purchasing the new drillpipes and maintenance of the rig itself.
First Deployment of Expandable Liner Hanger and Tie-Back System with Metal-To-Metal Seal in Gas Well, Offshore Abu Dhabi
Authors: Yudhia D. P. , Seyfetdinov R. , Alhaj M. , Aziz M. Abdel , Rabis P. , Al Ameri S. M. , AlMarzooqi A. , Barbera R. , Sallam S. , Omar H.
Published: May 2023

Liner hanger operations and well integrity across the liner overlap have been always a challenge in the gas well. Conventional liner hanger relies on elastomeric devices as the primary sealing mechanism to isolate the liner lap strings, with two trips required to deploy the liner hanger, top packer and tie-back seal. This paper will introduce an expandable liner hanger/packer and tie-back system to isolate high pressure reservoir and problematic shale in Offshore Abu Dhabi.

The selected single-trip expandable XPak liner hanger/packer and tie-back system offers a metal-to-metal seal throughout the complete liner stack, with 17 to 24 inches of an expandable section on the hanger/packer body that generate sufficient metal-to-metal contact area between the liner and the host casing achieving a robust sealing device that is to be considered as a primary isolating barrier. Feasibility review of technology was then conducted, covering review of running procedure, risk assessment and success criteria (covering HSE, performance, integrity, and efficiency). Business case was issued to install the 13-3/8″ × 9-5/8″ system. The system was deployed in a gas well drilled in 2021. Cementing job of 9 5/8″ liner was conducted smoothly with liner string rotated at 10 rpm while pumping & displace cement. Liner hanger/packer was set with 4,400 psi, hanger setting was then confirmed with 70 klbs overpull and the setting tool was released by slacking off the drill string with 120 klbs.

The operation was conducted safely and with zero NPT. The system was successfully demonstrated by the effectiveness of the offered features and its running procedure. Liner and tie-back casing integrity was achieved and confirmed through successful pressure tests. Based on the trial result, the selected single-trip expandable liner hanger/packer and tie-back system achieved the defined success criteria. The actual time saving from deployment of single-trip expandable liner hanger/packer and tie-back system compared to conventional liner hanger in this application is 2.54 rig days. The detailed analysis and operation feedback will be beneficial to assess the suitability of this technology to overcome future drilling and integrity challenges.
An Optimized Approach to Reduce Well Duration in Re-Entry Wells with the Utilization of a Dual Objective Single Motorized RSS Run in 8.5in Deviated Sections in Onshore Concessions, Abu Dhabi
Authors: Akinlosotu Akintunde Olaniyi , Quintero Fernando , Baruno Agung , Al Rahma Rahma , Al-Jabery Razan , Al-Reyami Mazin , Bin Shamlan Abdulla , Ali Al-Bunni M , Yehia Mahmoud Mohamed , Ud Duja Badar , Arshad Hafiz
Published: May 2023

Traditionally, the standard procedure employed by ADNOC Onshore for re-entry wells sidetracked from a cased hole involved milling a window in the casing and followed by a dedicated elongation run with a mud motor bottom hole assembly (BHA) for kick-off and to achieve desired separation from the original casing/wellbore before pulling out of hole with the motor drilling assembly. This is then followed up with a rotary steerable plus measurement/logging while drilling (M/LWD) assembly to continue drilling the 8-1/2″ deviated section to target landing point (LP). The main reasons for having the dedicated motor elongation run are to get enough separation from the main wellbore (not tracking the original hole) within the shortest distance to avoid the magnetic interference to the M/LWD tools from the casing and to assure not following the previously drilled well. However, associated with this practice are some negative impacts operationally which can be summarized as below

– High localized dogleg severity (DLS) during the sliding interval with the motor – Requirement to make-up and round-trip two separate BHAs before drilling to planned LP – Potential hanging of the motor assembly at the window during sliding interval – Additional cost due to utilizing 2 different types of drilling bit (Initially TCI for the motor run and then PDC to drill the section)

The only way to avoid those cons is by doing one trip with RSS to exit the window and drill away from the whipstock. The main challenge doing this will be to have enough rat hole to accommodate the BHA (including smart tools with electronics parts) and avoid damaging the BHA components during rotating it inside the casing. This can and has been achieved with a high build rate RSS by some operators but however, use of this technology still exposes the delicate components of the M/LWD tools to possible damage due to contact with the window while rotating the string with the tools still within the parent casing.

The introduction of the motorized rotary steerable system (MRSS) in the suite of steerable drilling assemblies has opened additional window of opportunities. Ability to combine some of the benefits of using a mud motor with that of a rotary steerable system all in one bottom hole assembly without doubt offers the potential of pushing further the limit of performance and productivity. With the MRSS BHA, with a minimum required rathole drilled with the whipstock milling assembly, the rotating part of the BHA will be out of the window prior to start circulation. This paper presents the success achieved with a MRSS system with Near bit Gamma-ray sensor requiring only 18ft rat hole delivered in ADNOC Onshore re-entry wells sidetracked from whipstock window.
Positive Impact of V0 Multi-Stage Cementing Tool on the Long Term Well Integrity
Authors: Hussain M. Q. , ALRashdi A. A. , ELMahdy M. M. , Mwansa P. L. , Amorocho A. , Ibrahim A. M. , Naga H. , Kaddoura I.
Published: May 2023

Weak formations which require isolation from elevated hydrostatic pressures during cementing operations have always been a challenge in the oil and gas industry. This paper will discuss the impact of deploying V0 Multi-Stage Cementing tool in terms of cement quality, well integrity and cost optimization.

The losses experienced throughout the extended 9-5/8" casing strings resulted in reduction of the cement quality exposing the full well integrity to higher risks. Meetings have been held between engineering, material, production optimization and operation teams to evaluate the current performance and identify methods for improvement. V0 Multistage cementing tool was introduced as a unique solution which would assure reaching expected well integrity, overcoming hydrostatic pressure challenges, and eliminating risks of poor cement quality in the corrosive environment gas well applications.

V0 Multistage cement tool has been successfully deployed for cases where elevated hydrostatic pressure was considered an issue, showing success in providing the required cement quality. Alternative methods to provide similar quality would be Liner hanger system followed by a tie back which would involve more associated cost, rig time and equipment.

Wells with high differential pressures due to fluid losses have been successfully resolved avoiding risks of performing single stage cementing, compromising zonal integrity of weaker formations and poor cement quality.

Qualified V0 Multistage cementing tool as per (ISO) 14310 V0 standard has been deployed, where gas-tight mechanical packer has enabled more reliable multistage cementing jobs for deep gas applications which ensured consistent and reliable gas-tight well integrity.

V0 Multistage tool was considered an economical solution reducing the cost by 70% compared to alternative solutions, reducing average of 3 rig days.

The paper will introduce the optimum economic solution for recurrent cementing challenges in both onshore and offshore operations. Utilizing latest technologies to retain wellbore integrity, eliminate unnecessary costs and reduce rig time.
Integrated Logistics Cost Optimization Through Automated Forecasted Drilling Operations Report
Authors: Hussain M. , AlRashdi A. , El-Mahdy M. , El-Kasrawi A. , Ibrahim A. , Mizukami A. , Zherelyev A. , Varga S.
Published: May 2023

Oil and gas companies continuously invest on digital transformation, to economically improve logistics workflow and enhance service providers interaction. A unique digital solution has been designed to automate business processes and reduce unexpected deviations from drilling operation execution process; to avoid unplanned costs and delays affecting overall drilling performance. The manuscript will focus on drilling process modifications and performance impact resulted from implementing drilling forecasting approach for materials and services.

Company and Software Provider jointly developed and implemented drilling forecast Report on top of existing reporting system to support drilling operations execution as per short- and long-term plans set earlier. Overall workflow and interconnection logic of steps were defined based on current Company's Standard Operating Procedures detailing Drilling Operation Policies and Instructions. Which ensured the software solution to be fully compliant with Company requirement. The developed automated Report passed a series of comprehensive tests in real conditions and after proven success; was decided to be implemented in Production environment to be efficiently utilized.

Following the specific logic of Company's drilling operations execution, the automated forecast report improved planning procedures and automated the information exchange between Company and respective Service Providers to support smooth logistics of materials and personnel that required to be delivered to rig sites or removed from it. Implementation of first phase required strong dedication of drilling engineers, the developed report was designed to eventually lighten the current workload and release additional man-hours in future to analyze and optimize existing procedures. As a digital solution, the report was designed to gather required information from different data sources and automatically compare it with current drilling operations status; to evaluate current phase and predict accordingly the next 10 days of forecast for drilling operations, materials to be prepared and personnel to be located. Which helped to assure materials and field engineers availability on rig site on time. Assuring cost saving and avoiding unplanned logistics costs due to potential deviation and optimized overall Company's financial burden.

The forecast report is being developed to be auto generated and shared on daily basis for all rigs to be available for all suppliers on daily basis.

Automated forecast Report implanted on top of existing database is enriching current reporting system. Utilizing a digital and automated approach for forecasting daily operation and planning tool for services and materials ahead of time would improve drilling performance efficiency, eliminate any unwanted delays and complement Company's digital strategy.
Drilling Beyond the Extended Boundaries of Complex Extended Reach Well
Authors: Hashmi Muhammad Asef , Al Suwaidi Muna , Salem Gamal , Al Yamani Sultan
Published: May 2023

Well was drilled in Al Nouf field with the objective to support the pressure sustainability of multiple producer wells across SH formation based on MRC / ERD approach. This paper presents the challenges faced in planning and drilling of subject well with departure of above 15,000ft and soft landed above the reservoir and later drilled 8.5" hole section to total measured depth of above 37,605ft (11.642 km) with having horizontal section of above 20,000ft with directional difficulty index (DDI) of 7.541 using heavy casing design.

Planning of this well commenced by meetings and collaboration with subsurface operation and reservoir team with the common objective of drilling a well of over 15,000 ft of departure and keep the well smooth for drilling long eMRC horizontal section. New technology was used with a common objective to achieve the goal and make trajectory smooth to provide max chance for lower completion to reach the max TD of the well.

All the associated risks were highlighted and mitigated by proper planning and engineering analysis such as trajectory, collision risks, BHA, hydraulics and casing design.

This eMRC/ERD well of above 37,605ft MD (4.12 ERD H:V ratio) is the first well in the region to successfully completed even with directional difficulty index (DDI) of 7.541

This paper will explain the innovative and novel approach of mitigating the challenges faced while drilling a complex well of 15,000ft departure and have an extended horizontal section of over 20,000ft with 8.5" drainage. A few challenges like drilling across the faults across horizontal hole section and collision risk at deviated and horizontal section were major concern but successfully catered with advanced engineering analysis and innovative technologies like torque reducer, turbo caser and swivel master etc.

Results from this well have proven that having lower completion in MRC / ERD wells have significantly improved the well accessibility and well performance and enhanced the reservoir management and significantly reduced the field development cost.

This paper summarizes the practice and technology used to successfully drill the MRC / ERD well in artificial island.

The challenges and its mitigation explained in this paper will support the idea to plan and drill the well beyond the reservoir boundaries to gather more data and to enhance more production. Also, this paper will provide novel approach of having lower completion in MRC/ERD wells which helps to attain more control on injectivity / productivity of reservoir because of proper isolation by swell packers and have maximum well accessibility across ERD horizontal section.
A Novel Solution on Integration of Engineering and Geology
Authors: Zhu Jun , Zhang Wei , Zeng Qijun , Liu Zhenxing , Liu Jiayi , Liu Junchen , Zhang Fengxia , He Yu , Xia Ruochen
Published: May 2023

In the past decade, the operators and service companies are seeking an integration solution which combines engineering and geology. Since our drilling wells are becoming much more challenging than ever before, it requires the office engineer not only understanding well construction knowledge but also need learn more about geology to help them address the unexpected scenarios may happen to the wells. Then a novel solution should be provided to help engineers understanding their wells better and easier in engineering and geology aspects. The digital twin technology is used to generate a suppositional subsurface world which contains downhole schematic and nearby formation characteristics. This world is described in 3D modelling engineers could read all the information they need after dealt with a unique algorithm engine. In this digital twin subsurface world, the engineering information like well trajectory, casing program, BHA (bottom hole assembly) status, are combined with geology data like formation lithology, layer distribution and coring samples. Both drilling or completion engineers and geologist could get an intuitive awareness of current downhole scenarios and discuss in a more efficient way. The system has been deployed in a major operator in China this year and received lot of valuable feedback from end user. First of all, the system brings solid benefits to operator's supervisors and engineers to help them relate the engineering challenges with according geology information, in this way the judgement and decision are made more reliable and efficiently, also the solution or proposal could be provided more targeted and available. Beyond, the geology information from nearby wells in digital twin modelling could also provide an intuitional navigation or guidance to under-constructed wells avoid any possible tough layers via adjusting drilling parameters. This digital twin system breaks the barrier between well construction engineers and geologists, revealing a fictive downhole world which is based on the knowledge and insight of our industry, providing the engineers necessary information to support their judgement and assumption at very first time when they meet downhole problems. For example, drilling engineers would pay extra attention to control the ROP (rate of penetration) while drilling ahead to fault layer at the first time it is displayed in digital twin system, which prevent potential downhole accident and avoid related NPT (non-production time). The integration of engineering and geology is a must-do task for operators and service companies to improve their performance and reduce downhole risks. Also, it provides an interdisciplinary information to end user for their better awareness and understanding of their downhole asset. Not only help to avoid some possible downhole risks but also benefit on preventing damage reservoir by optimizing the well construction parameters.
Optimization of Lateral Length and Risk Assessment Based on Wellbore Undulations
Authors: AlGobi Ghaleb. A. , Samuel Robello
Published: May 2023

The success of drilling new horizontal wells depends on connecting the well’s surface location with the targeted formation while achieving the desired lateral length. However, the choice of the surface locations can be limited due to difficulties obtaining the permits to drill on these locations. This creates more deviated wellbore designs and decreases the optimized lateral length. To avoid this, a risk matrix will be developed to evaluate the maximum lateral length for different surface locations.

The first step to creating the risk matrix is to derive a geometry-focused torque and drag model. This model will utilize the wellbore’s step-out and geometrical torsion, which are resulting of both a deviated well design and a far surface location. In this paper, the step-out for any given well path design will be considered as the sum of the horizontal projections of all the deviated segments of the well trajectory above the last curve’s KOP. The calculation of the step-out will be incorporated into the model, then will be used to calculate the maximum lateral length versus the step-out.

A torque and drag model with the simplicity of the soft-string model was created while taking into consideration the wellbore’s geometrical torsion to capture the effect of the well’s trajectory on the axial forces and the torque. This effect will partially simulate the deformation of the drill pipe using simplified mathematical expressions comparing to the calculations of the stiff-string model. This methodology resulted in the model to be more sensitive to the axial force than the torque.

The built risk matrix uses the derived model to highlight one of two mechanisms that determine the dominant constraint that limits the drilling process: either reaching the maximum hook load or the maximum torque, based on the wellbore design. These limits depend on the rig’s capacity and the drilling company. The risk matrix summarizes multiple designs to conveniently compare between different step-out values and their respective maximum later lengths. The risk assessment is quantitative rather than qualitative and is reflected as the percentage used of the dominant constraint for the given designs and the interval of the lateral lengths at which this percentage is reached. The optimum surface location with its step-out is then chosen easily from the created risk matrix.

The built model takes a middle position between the soft-string model and the stiff-string model by capturing the geometrical torsion along the wellbore trajectory. This approach enhances the geometrical optimization when calculating the axial force and the torque. The simplified mathematical derivation incorporates the step-out into the model, thus creating the risk matrix to optimize the lateral length based on the surface location.
Improvement of Slot Recovery Performance with Hollow Bit Technology by Recovering Fully Cemented Dual Casing in Offshore Abu Dhabi Oil Field
Authors: Fukuda K. , Biyanni H. , Toma M. , Moslim S. , Toki T. , Zaabi A. Al
Published: May 2023

Hollow bit method was introduced and implemented in Offshore Abu Dhabi Field to eliminate the cement quality uncertainty and improve the slot recovery performance. Hollow bit method improved the overall slot recovery performance by 40% compared to other slot recovery methods, reducing operation duration from 20.8 days to 12.5 days. In this paper, hollow bit technical overview and best practices which can be implemented to similar application are presented
Successful Fit-For-Purpose Coiled Tubing Catenary Sand Cleanout on a Monopod Platform at Offshore East Malaysia – Operator Case Study
Authors: Awang Atim F. , Sipangkui R. B. , Karim M. , Pacifico E. , Aripin I. , Sujavudin M. , Sy M Shahril S. , B M Nor M Abshar , Fidzrus I.
Published: May 2023

Coiled Tubing (CT) operations on small platforms pose multiple challenges, more so at a monopod. Resolution of apparent challenges, including worksite limitations and returns handling, led to new issues that needed to be addressed and overcome. This paper will discuss in detail, the case study of a CT Catenary campaign that addressed all challenges resulting in the first execution of high-complexity sand cleanout operations on a monopod platform at offshore Sabah, Malaysia by the Operator.

The approach commonly used in the region to perform sand cleanout at small platforms is using a work barge or workboat-assisted CT with sand-handling equipment placed on the platform's main deck. For this monopod facility, in addition to adopting a CT catenary solution to reduce monopod deck loading, further load reduction requirements on the structure necessitated a reassessment of sand-handling equipment placement, specifically on the supporting workboat. This approach required the development of safe, effective, and practical returns management between the workboat and the platform.

During the planning stage, the team established that a compact and fit-for-purpose operational set-up was required to meet the approved project economics. It was identified that detailed program engineering, comprehensive operational planning, personnel competency upskilling, and specific equipment optimizations would collectively be critical to the success of the sand cleanout campaign. In addition to the main scope of removing sand build-up in the well completions, the campaign also involved additional CT fishing and pumping activities. These additional scopes required the work program to be sufficiently robust to address potential operational contingencies yet flexible enough to meet all scope requirements for the equipment layout without the workboat having to return to the mobilization port for layout changes.

The value presented in this paper comes from the comprehensive and detailed discussion of all technical and operational issues resolved by the Operator and its Solution Partner, in performing CT catenary cleanouts at a remote, small-size monopod facility. The paper also shares the final configuration and arrangement by which the campaign was executed and completed for insight sharing and further improvements.
Study on the Wellbore Reconstruction Refracturing Technology Based on Expandable Tubular
Authors: Guo H. J. , Zhou Y. , Wang B. D. , Zhang Q. L. , Xu B. G. , Jao T. , Zhou S. H.
Published: May 2023

Refracturing is a promising means to improve the output and estimated ultimate recovery of shale oil and gas resources, which is an efficient method to recover the productivity of low permeability old wells. Refracturing has achieved good results in the development of shale gas wells in North America, and has increased output and decreased the extraction cost significantly of shale gas resources. The disadvantage of unable to control the fracturing fluid accurately of the conventional temporary plugging diverting refracturing technologies like chemical particulates has been exposed in the applications.

Wellbore reconstruction technology based on the solid expandable tubular (SET) was studied in this paper, which is a permanent plugging diverting refracturing technology with a high sealing effect and simple operation. Technical principles, tool structures and construction processes were analyzed and relative laboratory tests were conducted to verify the feasibility of this technology. Meanwhile, comparisons between expandable tubular technology and other refracturing technologies were developed to analyze the application prospect in shale oil and gas resources.

The indoor tests indicated that wellbore reconstruction technology based on expandable tubular can plug the perforation on the casing effectively with certain sealing pressure, which showed that this technology can realize the wellbore reconstruction to create the wellbore conditions for the next fracturing work. Compared with other temporary plugging refracturing technologies, the expandable tubular technology can achieve accurate control of fracturing fluid and has a better effect of refracturing work. At the same time, it has the advantages of simple operation and big internal diameter compared to other wellbore reconstruction methods like casing plugging technology, which means that bigger displacement can be used and better effect can be achieved in the refracturing work.

The conclusions obtained in this paper can promote the development of wellbore reconstruction technology based on expandable tubular, which provides a theoretical reference for the design of the refracturing work in shale oil and gas resources.