bluuebunny/crossref_metadata_2025 huggingface dataset:
ANALISIS PENURUNAN MUTU BETON STRUKTURAL AKIBAT PENGARUH AIR LAUT PADA MASA PEMELIHARAAN
Authors: Uu Saepudin  , Sumarno Wahyu , Ega Mardiana Cecep
Published: February 2023

Air laut memiliki kandungan garam yang tinggi yang dapat menggerogoti kekuatan dan keawetan beton. Hal ini disebabkan klorida yang terdapat pada air laut yang merupakan garam yang bersifat agresif terhadap bahan lain, termasuk beton. Kerusakan dapat terjadi pada beton akibat reaksi antara air laut yang agresif yang terpenetrasi ke dalam beton dengan senyawa-senyawa di dalam beton yang mengakibatkan beton kehilangan sebagian massa, kehilangan kekuatan dan kekakuannya serta mempercepat proses pelapukan (Mehta, 1991). Sehingga perlu dilakukan penelitian tentang penurunan mutu beton struktural akibat pengaruh air laut pada masa pemeliharaan.

Tujuan dari penelitian ini adalah mengetahui pengaruh air laut pada masa pemeliharaan terhadap penurunan kuat tekan dan kuat lentur beton struktural dan mengetahui penurunan kuat tekan dan kuat lentur beton struktural terbesar. Metode yang digunakan dalam penelitian ini adalah metode eksperimen. Penelitian dirancang dengan 5 perlakuan untuk uji kuat tekan beton dan 5 perlakuan untuk uji kuat lentur beton, masing – masing diulang 3 kali. Perlakuan yang diujicobakan antara lain beton dengan mutu K 200, K 250, K 300, K 350 dan K 400.

Hasil penelitian menunjukan bahwa pemeliharaan beton dengan menggunakan air laut berpengaruh terhadap kuat tekan dan kuat lentur beton dimana terjadi penurunan kuat tekan dan kuat lentur beton. Penurunan kuat tekan beton K 200 sebesar 17,32%, beton K 250 sebesar 16,34%, beton K 300 sebesar 14,93%, beton K 350 sebesar 11,11% dan beton K 400 sebesar 9,33%. Penurunan kuat lentur beton K 200 sebesar 15,56%, beton K 250 sebesar 15,11%, beton K 300 sebesar 13,03%, beton K 350 sebesar 10,34% dan beton K 400 sebesar 9,25%. Penurunan kuat tekan dan kuat lentur beton  terbesar akibat pengaruh air laut pada masa pemeliharaan terjadi pada beton K 200 dengan penurunan kuat tekan sebesar 17,32% dan penurunan kuat lentur sebesar 15,11%.
KONTRIBUSI PELATIHAN DIGITAL MARKETING BERBASIS GAMIFIKASI TERHADAP KOMPETENSI PEMASARAN IKM (INDUSTRI KECIL MENENGAH)
Authors: Uswatun Habibah Nunung
Published: February 2023

Dewasa ini IKM makanan di Ciamis menghadapi tantangan persaingan pasar di era digital, dimana umumnya IKM makanan di Ciamis basis pemasarannya masih menggunakan cara-cara tradisional, sehingga selalu tertinggal dari IKM makanan yang telah menggunakan pemasaran digital, hal tersebut disebabkan masih sangat kurangnya pengetahuan dan pemahaman pelaku usaha IKM makanan di Kabupaten Ciamis tentang sistem digital marketing telah menjadi andalan dalam dunia pemasaran saat ini dan telah menjadi bagian perekonomian nasional yang berpotensi dapat meningkatkan kesejahteraan masyarakat. Untuk itu, kontribusi pelatihan dalam peningkatan akses dan jangkauannya sangat dibutuhkan untuk bisa menghadapi persaingan tersebut. Tujuan dalam penelitian ini adalah menentukan kontribusi pelatihan digital marketing berbasis gamifikasi terhadap kompetensi pemasaran IKM Makanan di Kabupaten Ciamis. Metode penelitian menggunakan survai eksplanatori, teknik pengumpulan data melalui kuisioner. Menentukan sampel digunakan teknik sensus. Teknik analisis data untuk mengetahui kontribusi antara variabel digunakan koefisien korelasi Pearson, koefisien determinasi, regresi linier sederhana dan pengujian hipotesis menggunakan uji t. Berdasarkan hasil penelitian diketahui bahwa pelatihan digital marketing berbasis gamifikasi pada IKM makanan secara umum masih dianggap kurang.  Kompetensi pemasaran IKM makanan di Kabupaten Ciamis secara umum masih tergolong pada katagori sedang karena masih fluktuatifnya tingkat penjualan. menunjukan bahwa pelatihan digital marketing memiliki kontribusi terhadap kompetensi pemasaran IKM di Kabupaten Ciamis adalah sebesar 68,72 %, dan sisanya sebesar 31,28 % kontribusi dari variabel lain yang tidak diteliti
Perceived Stress and Psychological Distress among Nurses during the COVID-19 Pandemic
Authors: Ghorbanzadeh Kobra , Negarandeh Reza , Zarei Nafiseh , Takleh Mehdi Piri , Eghbali Mohammad
Published: February 2023

The advent of COVID-19 has significantly affected healthcare workers’ mental health. This study was conducted to investigate the perceived stress and its relationship with psychological distress among nurses who took care of patients with the COVID-19 disease. This cross-sectional study was performed on 180 nurses in Ardabil province in 2020. Data were collected online through two standard questionnaires, making use of the Cohen Perceived Stress Scale and the Kessler Psychological Distress Scale (K10). Then, data were analysed based on descriptive and analytical statistics using SPSS software version 19 as well as independent t-tests, Spearman’s correlation coefficient, and multiple linear regression tests. The results of the Spearman’s correlation test indicated that there was a significantly positive correlation (rho = 0.79) between perceived stress and psychological distress (P <0.001). After adjusting the effects of other variables using a multiple linear regression test, the beta correlation coefficient was calculated, and the obtained value of 0.766 was regarded as statistically significant (P <0.001). Moreover, 63.9% of the nurses experienced moderate perceived stress, and 72.6% experienced severe mental disorders. The results of this study demonstrate that high perceived stress is considered as a strong predictor of psychological distress, and also the majority of the nurses working in frontline wards have experienced severe psychological distress. Therefore, it is recommended to take into account the workplace stress and prepare the ground (e.g., through preparing education, identifying at-risk individuals, as well as providing psychotherapy services and social support) to reduce the stress and promote the nurses’ mental health.
ASP Formulation Development Journey, Optimisation and Validation for Mangala Field
Authors: Koduru Nitish , Prasad Dhruva , Pandey Amitabh
Published: February 2023

Mangala is a large low salinity, high quality fluvial oil field reservoir in India with STOIIP of over one billion barrels of waxy and moderately viscous crude. Aqueous based chemical EOR has been identified as the most suitable technique to improve recovery over waterflooding. The objective of this paper is to describe the ASP formulation development journey for Mangala which involved more than 30 corefloods till date with evolution of formulation design changing over time. The final selected formulation has been successfully tested in upper layer of Mangala field during pilot and is being planned to be used in full field.

Initial formulation design was done using IFT (interfacial tension) and adsorption measurements approach. Later the formulation design was done using classic phase behavior approach which allowed quick and robust evaluation of large number of chemicals in a short duration. Typically, the formulation development involves phase behavior tests, aqueous stability test, salinity gradient design, dead oil and live oil coreflood on long linear synthetic and reservoir core plugs. A successful formulation shall have low viscous microemulsion phase, solubilization ratio greater than 10 (ultralow IFT), very low residual oil saturation, good thermal and aqueous stability, low adsorption, low chemical concentration and fewer components among many other parameters.

Initial formulation basis IFT measurements was selected and tested under multiple corefloods (IPTC 12636). Later, basis the phase behavior approach, another formulation consisting of 0.3% surfactant and 0.3% co-solvent was formulated (SPE 129046). For Mangala, solubilizing paraffinic waxy crude required usage of large carbon chained Alkyl Benzene Sulfonate. Formulation with hydrophobic surfactant required addition of a hydrophilic surfactant and a co-solvent. Co-solvents, though improve electrolytic strength, add significant chemical cost and are some-times unstable. Finally, a highly hydrophilic alcohol alkoxy sulfate was selected to substitute the role of co-solvent but still maintain enough electrolytic strength. The formulation consisted of 0.3% surfactant, 3% alkali and 0.25% polymer in soft water which was used during a successful pilot (SPE 179700).

The formulation has been further optimized to reduce the overall chemical quantity (SPE 200445) to 0.25% surfactant and 2.5% alkali. Additionally, formulation has been validated on other layers of Mangala field under high pressure live oil phase behavior and live oil reservoir coreflood.

This paper discusses ASP formulation development approach, technical requirement, development journey of formulation for successful Mangala ASP pilot, optimization efforts undertaken to reduce the chemical usage and validation of formulation for other layers of Mangala reservoir. This paper also briefly discusses lab quality control guidelines that is being developed for large scale procurement of chemicals for full-field ASP floods.
Like Cures Like Microbial Enhanced Oil Recovery in Biodegraded Crude
Authors: Ketmalee Thanapong , Singhapetcharat Thanachai , Pancharoen Monrawee , Navasumrit Pacharaporn , Chayraksa Kittiphop , Kovitkanit Naruttee
Published: February 2023

Field A is an onshore oil field in Thailand. This area contains biodegraded medium-heavy crude reservoir; 19°API oil gravity and 144 cp viscosity. Therefore, the field suffers from a low recovery factor due to high crude viscosity.

On one hand, bacteria have exerted an adverse effect on production, on the other hand, it means that the condition of the reservoir is suitable for implementing Microbial Enhanced Oil Recovery (MEOR). The MEOR is a technology that utilizes microorganisms (mainly bacteria), to enhance oil production, especially for medium-heavy oil. By feeding nutrients to bacteria, several metabolites were produced that would be useful for oil recovery. This technique is well known for its low investment cost, hence, high return.

The technical screening confirmed that the reservoir and fluid properties are suitable for MEOR. Consequently, sixteen core samples and three water samples were collected for indigenous bacteria analysis. Although the laboratory indicated there are countless bacterial strains in the reservoir, the nitrate-reducing biosurfactant-producing bacteria group was identified. This bacteria group belongs to the Bacillus genus which produced biosurfactant and reduced crude viscosity by long-chain hydrocarbon degradation.

Therefore, the treatment design aimed to promote the growth of favorable bacteria and inhibit undesirable ones. Consequently, a combination of KNO3 and KH2PO4 solutions and a specialized injection scheme was tailored for this campaign.

The pilot consisted of two candidates those were well W1 (76% water cut), and well W2 (100% water cut). The campaign was categorized into three phases, namely, 1.) baseline phase, 2.) injection and soaking phase, and 3.) production phase. Firstly, the baseline production trends of candidates were established. Secondly, KNO3 and KH2PO4 solutions were injected for one month then the wells were shut-in for another month. Lastly, the pilot wells were allowed to produce for six months to evaluate the results.

The dead oil viscosity of well W1 was reduced from 144 cp to 72 cp which led to a 6.44 MSTB EUR gain or 1.3% RF improvement. On the other hand, the productivity of well W2, the well with 100% water cut, was not improved. This was expected due to insufficient in-situ oil saturation for a bacteria carbon source. Considering the operational aspect, there was no corrosion issue or artificial lift gas-lock problem during the pilot.
The First Steam Flooding Design and Application for Thin Heavy Oil Reservoir in Bohai Bay by Horizontal Well
Authors: Pan Guangming , Luo Xianbo , Zhang Lei , Li Hao , Qu Jifeng
Published: February 2023

The target heavy oil reservoir was developed by horizontal wells with large well spacing (250 m ~ 450 m) during the early huff and puff stage. However, more than 70% of the reserves was left in the reservoir after stimulation development because of its small heating radius, and required further enhanced oil recovery through subsequent steam flooding for inter-well reserves extraction.

Different from traditional vertical well, a special hot-water condensate zone developed at the reservoir bottom due to vertical radial flow during horizontal well steam flooding was demonstrated in our previous work. Inhibiting the development of hot-water condensate zone became the design key for horizontal well steam flooding. Based on laboratory physical experiments and numerical simulation method with 13 years of huff and puff development history match, the first offshore steam flooding scheme was studied to optimize and obtain the main heat injection parameters. Finally, field practice was carried out 30 months ago to verify project design.

Results showed that, compared with mature vertical well steam flooding designed for suppressing the overlap in top steam zone, the horizontal steam flooding was designed to suppress channeling flow caused by weak stability of hot-water displacement oil front in bottom condensate zone. Therefore, the heat injection well was designed in the low structure position for horizontal well steam flooding, while designed heat injection well for vertical well steam flooding located in the high structure position. Meanwhile, to ensure effective expansion of steam zone, the production/injection ratio was optimized as high as 1.4 to 1.6 for horizontal well steam flooding, rather than low production/injection ratio of 1.2 to 1.4 for conventional vertical well. Also, it was demonstrated that foam can effectively prevent steam channeling under high oil saturation conditions, especially in the high superheated temperature. So the profile control timing for horizontal well was advanced in the early thermal connection stage, instead of the late steam breakthrough phase for vertical well. The field practice has been carried out for 30 months, the daily oil production of well group increased from 180 m3 to 250 m3, and the instantaneous oil/gas ratio was developed as high as 0.8 to 1.0.

It was suggested to pay special attention for the additional hot-water condensate zone at the reservoir bottom for horizontal well steam flooding. The proven development strategy, inhibiting condensate zones at reservoir bottom and promoting steam zones at reservoir top, customized for horizontal well can also be applied in offshore similar thin heavy oil reservoirs with large well spacing.
Acid-Induced Emulsion and Sludge Mitigation: A Lab Study
Authors: Alhamad Luai , Alfakher Basil , Al-Taq Ali , Alsalem Ali
Published: February 2023

Acid matrix stimulation is a widely used method to improve well productivity by removing and/or bypassing damage in the near wellbore area and creating channels for hydrocarbon flow. Hydrochloric (HCl) and organic acids are commonly used to design fluid recipes utilized in these treatments. However, these acids can cause formation damage by forming stable emulsions and sludge upon contact with formation crude if the treatment and/or stimulation fluid are not designed carefully. It is well reported that acid in contact with crude oil can destabilize asphaltenes either by neutralizing asphaltene or dissolution of resins. Therefore, acid recipe chemical additives must be selected and examined carefully to ensure effective acidizing treatments.

In this study, the interaction of different HCl-based recipes with oil was investigated using different lab techniques and analysis including acid/oil separation tests, sludging tendency testing, and SARA analysis. The influence of several factors including acid concentration, acid type, and dissolved iron content were investigated. Experiments were conducted with varying acid blends, demulsifier and anti-sludge type and concentration. To simulate dissolving corrosion products by acids in downhole environment, ferric chloride was incorporated in acid recipes.

The results showed an increase in temperature enhanced emulsion/sludge breaking tendency. The addition of demulsifier/anti-sludge agents in acid recipes was necessary to avoid creating stable emulsions and sludge that can damage reservoir permeability. Higher amounts of dissolved iron in the acid solution resulted in a more stable emulsion and enhanced sludge formation. Asphaltene problematic oil, as determined from the asphaltene colloidal instability index, showed severe sludging tendency. Lastly, the use of HCl/organic acid blends may be necessary for some oil types to avoid formation of sludge.

This paper showcases a comprehensive testing method to mitigate formation damage from acidizing treatments. The testing can be expanded to design an acid stimulation fluid recipe to minimize acid-induced formation damage and maximize well productivity enhancement.
A New Multistage Fracturing Completion Approach for Sanding Formations: First Application in the Region
Authors: Rodoplu Rasim Serdar , Brohi Imad G. , Al-Mohanna Khalid S. , Qahtani Adel A.
Published: February 2023

Different approaches and techniques were utilized in the industry to overcome challenges in sanding formations, including frac-packs, indirect fracturing, and resin coated proppants. Due to complexities in the results achieved, open hole multistage fracturing (OH MSF) with a sand control completion system was introduced with the goal of expanding the technology portfolio for controlling sand production and proppant flowback.

Offset wells drilled in a prolific gas-bearing unconsolidated sandstone formation showed high sand and proppant production restricting the potential from these wells. Therefore, it was necessary to develop a new OH MSF completion strategy to address sand/proppant control and combine it with proppant fracturing at the same time. This paper highlights OH MSF technology that utilizes screened port sleeves capable of withstanding fracturing pressures and harsh environments.

The new completion system consists of a hydraulic frac port opened by applying pressure in the first stage. In addition, the fracturing ports for the next stages are opened by dropping activation balls. Each stage needs to be equipped with a sleeve fused with a screen for sand and/or proppant control. Stages are separated by open hole packers for zonal isolation in the open hole section. It is an innovative system that combines MSF completion with sand control components.

Due to the complex nature of the completion, rigless well intervention operations must be well planned, discussed, and conducted with close monitoring during all the operations. In particular, frac port opening/closing, sand screened sleeves opening with coiled tubing (CT) well interventions, proppant fracturing operations, and e-line production logging tools (PLTs). Besides, if the transmissibility is high with a high leak off and quick closure of fracture, then frac operations should be performed with the objective of creating a tip screen out (TSO) scenario to achieve good proppant packing close to the wellbore area.

Production rates after completing proppant fracturing, CT milling, and shifting interventions exceeded the expectations without any sand or proppant flowback. The candidate well's rate remained higher than offset wells and no sand nor proppant were observed on the surface.

The new OH MSF with sand control completion technology will enable performing OH MSF treatments in gas formations with a high sanding tendency. In addition, it helps to diversify technologies utilized to enhance production without producing formation sand or proppant. Utilization in the right candidate in conjunction with an optimum engineering approach and optimized design will ensure obtaining the benefits of this new completion system to overcome similar challenges.
A Breakthrough Solution to Set ESP Packer at Higher Inclination by a Creative Combination of Re-Designing Slick-Line Tool String, Completion String and Well Trajectory Saving up to 30% of Completion Time in a Middle East Depleted Oil Field.
Authors: Almuallim Mustafa , Ullah Syed Zahoor , Ruzhnikov Alexey , Silva Paul , Al Shaikh Jaffar , Agarwal Rohit , Al-Herz Mohammad
Published: February 2023

After years of oil production in the Middle East, conventional electric submersible pump (ESP) placement at inclination of 45° is no longer deep enough to enable inflow of hydrocarbons. As a result, in some fields a packer placement is pushed deeper and closer to a reservoir at 55°-70° inclination which negatively impacts the ability to set packer with conventionally slick-line run plug system. The paper provides information on technologies used to overcome challenges associated by use of creative solution of modified slick-line run tubing plug system aiming to set the production packers at high inclination, in excess of 45°.

This optimized system eliminates risk of weakened slickline jarring action across deviated wellbore by optimizing landing plug design, completion string configuration and landing profile criteria at which plug is deployed to pressurize tubing and set completion packer. The manuscript discusses torque and drag modeling utilized to plan and monitor deployment of modified slick-line system across high deviated and extended reach (ERD) wells. Finally, paper concludes with a detailed deployment BHA, execution road map and contingencies.

The abovementioned system was successfully implemented across 5 extended reach wells (ERD) with packer set at an inclination up to 70°. Revised approached enabled optimization of both slick-line BHA and completion string such, that cost is reduced by over 30% compared to other wells where packer was set with conventional approaches like coiled tubing and wireline tractor. Furthermore, time associated with completion operation has been reduced by more than 2 days. Utilized model of slick-line deployment is currently adopted by the operator as standard practice to set ESP packer across highly deviated trajectories for both multi- and single lateral extended reach oil wells.

The document provides a novel approach to set production packer at high inclination by utilization of optimized deployment BHA comparing to more expensive and time-consuming alternative approaches. It also provides technical feasibility analysis for slickline deployment into wellbores of high inclination. The proposed approach can be implemented any project worldwide to optimize both wireline and slick-line operation and thereby improving the performance.
Investigating the Effect of Thermal Conductivity on Geothermal Energy Production at Different Circulation Rates in an EGS Abandoned Case Study
Authors: Ashena Rahman , Madani Mohammad , Sivanesan Siva Kumar , Thiruchelvam Vinesh
Published: February 2023

The thermal conductivity coefficient of the reservoir formation rock-cement-casing combination is an important parameter affecting the optimum circulation flow rate in open and closed-loop systems. Despite its importance, an accurate value of the thermal conductivity may not used in modeling due to the fact that either the thermal conductivity of the rock and cement is not measured in the lab to be accurately known, or the effect of cement and casing thermal conductivities on the net thermal conductivity is ignored. Therefore, this work investigates the effect of a change in the thermal conductivity on the net heat energy, the net power and the coefficient of performance (COP), at different circulation rates.

The simulation results using CMG software for a high reservoir temperature shallow case study in Trindad and Tobago show that when the net thermal conductivity of 2 W/m/K is doubled, the net heat energy and power show minimal increase of up to ~1%. Such minimal increases are the case at all circulation rates, with the greatest heat increase occurring at the largest circulation rate. The minimal produced heat increase is attributed to the assumption of external reservoir temperature being at the nearest radius to the wellbore wall due to the fact that the high thermal conductivity of water in the fractures dominates and the fractures extend so far that the surface area for heat flow is very high. This is in accordance with previous research simulation results.
A Novel Approach to Sand Volume Prediction Using Machine Learning Algorithms
Authors: Shabdirova Ainash , Kozhagulova Ashirgul , Nguyen Minh , Zhao Yong
Published: February 2023

The objective of the paper is to discuss the application of different Machine Learning (ML) algorithms to predict sand volume during oil production from a weak sandstone reservoir in Kazakhstan. The field data consists of the data set from 10 wells comprising such parameters as fluid flow rate, water cut value, depth of the reservoir, and thickness of the producing zone. Six different algorithms were applied and root-mean-square error (RMSE) was used to compare different algorithms. The algorithms were trained with the data from 8 wells and tested on the data from the other two wells. Variable selection methods were used to identify the most important input parameters. The results show that the KNN algorithm has the best performance. The analysis suggests that the ML algorithm can be successfully used for the prediction of transient and non-transient sand production behavior. The algorithm is especially useful for transient sand production, where sand burst is followed by abrupt decline and finally stops. The results show that the algorithm can fairly predict the peak sand volumes which is useful for sand management measures. The variable selection studies suggest that water cut value and fluid flow rate are the most important parameters both for the sand volume amount and accuracy of the algorithm. The novelty of the paper is an attempt to predict sand volume using ML algorithms while existing studies focused only on sanding onset prediction.
Brilliant at the Basics: A Review on Dual String Gas Lift Injection Performance in Malaysian Offshore Fields
Authors: Suggust Alister Albert , Kueh Jing Zhi
Published: February 2023

Sarawak offshore wells are mostly completed with dual string completion and are heavily relying on gas lift as the primary artificial lift. Dual string gas lift is an economical way to selectively produce from multi-stacked reservoirs in Sarawak fields. However, it poses great challenges in terms of operations, troubleshooting, allocation and optimization as both strings share a common annulus. Dual string gas lift performance diagnosis need to be done from time to time to ensure the strings production are optimized at well level.

Gas injection rate is a critical input in predicting the well performance based on the gas lift performance curve. However, the gas lift injection rate for dual string is measured at well – not at string level. The gas lift injection rate into each string needs to be allocated correctly either through well modelling calibration approach, testing one string while shutting its neighbor or well tracer application. After allocating the gas lift injection rate into each string correctly, well modelling prediction run at done to mitigate multipointing issues, design optimum point of injection, establish optimum injection rate at well level and determine the optimum casing head pressure.

The operator has proposed for a workflow to correct the dual gas lift injection allocation based on well modelling calibration. The workflow was implemented and resulted in multiple optimizations in terms of gas lift valve change program, choke optimization and gas lift rate optimization. Apart from that, the paper will also share on the findings from the well tracer application in correcting the gas injection allocation.

This paper will focus on the production performance check on dual string gas lift performance at well level. The findings from the study are subsequently monetized as quick-gain opportunities while the operator is embarking into long term study on assessing the alternative artificial lift strategy suitable for a brownfield. The lessons learned will also be applicable to oil fields with similar situations to further improve the fields’ production.
Play-Based Evaluation on Permian Carbonate Reservoir: Implications for Petroleum Exploration in Northeast Thailand
Authors: Benny Hendra , Benjawan Teekayu , Chaichana Kasame , Amonpantang Phinporn , Wongsuriyakat Natsinee , Ponsri Sirichon , Piwhom Prath , Chaibamrung Phongsakorn
Published: February 2023

Despite the long exploration history, success rate has been low in the Khorat Plateau region of northeastern Thailand. To date, only two gas fields (from 9 discoveries) have been produced from Permian carbonate reservoirs, the only successful play. PTTEP and Department of Mineral Fuels (DMF) of Thailand conducted a collaborative basin-wide study using a Play-Based Exploration (PBE) method to fully understand the remaining prospectivity. PBE combines all aspects of petroleum system to provide a holistic view on basin prospectivity. It integrates existing knowledge in literature with well failure analysis, well-seismic stratigraphy, reconstruction of paleogeography and depositional environments, structural interpretation and restoration, source rock characterization and 1D basin modeling into a comprehensive basin development model. The outcome from these analyses coupled with better understanding of the basin were used to generate common risk segment maps of key elements in the petroleum system. The common risk segments maps were combined into the total chance map, which was then used to identify play fairways. Two major rifting episodes during Carboniferous-Triassic and three compressional events during the Triassic and Paleogene resulting in closures of the Paleo- and Neo-Tethys Oceans were responsible for the complex tectono-stratigraphic history of this area. The deposition of marine source rocks and carbonate reservoirs were influenced by the Late Carboniferous to Permian rift structures. The Triassic and Paleogene compression subsequently created prospective structural traps as well as modified local reservoir qualities via fracturing and hydrothermal processes. The Permian carbonate reservoirs are sealed by a widely distributed Upper Triassic fluvial floodplain sediments. Play chance shows that the exploration sweet spots are related to karst features and fractures mainly in the western and north-western parts of the Khorat Plateau. Further detailed study and prospect level evaluation planned for these fairways. Identifying and delineating the karst features and fractures are key to success in future exploration. Additional infill seismic data will also help in achieving the goals.
Unravelling the Mystery of Double Complex Unconventional Reservoirs on Tibetan Plateau by Highly Integrated Geophysical and Geological Modelling
Authors: Tong Yanming , Chen Xiaodong , Zhang Qinghui , Wu Chuan , Tan Chenqing , Gao Farun , Guo Ning , Tan Wulin , Kosolpinete Monthathip
Published: February 2023

The study area belongs to Qaidam Basin of Tibetan Plateau. It has extremely complex structural and sedimentological conditions which seriously hinder in-depth geological understanding and effective exploration and development activities. We solve the problems to a great extent with highly integrated unique geophysical and geological modeling.

The solutions mainly included: (1) Continuously improving the quality of seismic image by updating the PSDM cube twice during project execution based on a unique workflow of Coupled Geophysical & Geological Modeling; (2) Adjusting/consolidating seismic structural interpretation, well tops, and structural information on microresistivity images reiteratively to obtain robust structural interpretations; (3) Structural modeling with the method suitable for complex structural background; (4) Property modeling with combined constraints of well data, seismic trend, sedimentary cycle, variogram and geological understanding, such as using element logging interpretation results for Lithofacies, Mineral composition and Porosity models; (5) DFN fracture modeling with fracture statistics from microresistivity images, seismic edge-detection cube, seismic drivers and NFP geomechanical drivers.

Not only are the double complex reservoirs effectively characterized, but also many meaningful geological conclusions are reached which in turn could guide more effective E&P activities, including (1) distributions of oil-bearing belts, pools, and high-production wells are all controlled obviously by structural patterns; (2) although the reservoirs belong to a very large lacustrine basin sedimentologically, great heterogeneity still commonly exists, with many local structural highs and lows causing quick variation of microfacies in plan view; (3) source rocks, reservoirs, traps and preservation condition are the key factors for oil abundance; (4) four geological conditions need to be carefully evaluated for any outskirt well design & drilling, etc.

Based on the results, measured OOIP of tens of millions of tons has been summitted to the country, a bunch of kiloton-oil exploration wells have been drilled and dozens of optimized development wells have been placed in recent years.

We realize "for the first time" in some aspects for effectively characterizing the saline lacustrine thin tight oil reservoirs on tectonically complex Tibetan plateau. This study can be referred to by other geologically complex regions in the industry.
Integrated Subsurface Reservoir Characterization to Enhance Geomodeling in the Suphanburi Oil Field, Onshore Thailand
Authors: Kunpitaktakun Takonporn , Boonyasatphan Prat , Utitsan Seehapol , Wongpaet Khuananong , Primadi Hari
Published: February 2023

To prolong the field life of The Suphanburi oil field, an additional enhanced oil recovery (EOR) process is required. Dynamic reservoir modeling will need to be performed to maximize the EOR strategy. However, achieving the right result is a challenge as the field has a complex depositional environment and high heterogeneity, resulting in a high uncertainty of the dynamic reservoir model. A new reservoir model is proposed and created. The new model has been purposely built to capture the heterogeneity of the field by incorporating the newly interpreted geological concept of the field, together with quantitative seismic interpretation results. First, the new geological concept is interpreted from well data into "depofacies". The depofacies describe both depositional environment and lithofacies. Next, quantitative seismic interpretation is performed to capture the spatial variation of the reservoir and the predefined facies. Lastly, the reservoir model is built by first generating the depofacies. The reservoir or sandstone is then modeled specifically into each pre-modeled depofacies. As a result, the new reservoir model can better capture reservoir heterogeneity, resulting in a better EOR strategy.
Innovative Approach to Enhanced Well Integrity Evaluation in Unconventional Completions with Fiberglass Casings
Authors: Hijles Ali A , Waluyo Fauzia , Singh Kamaljeet , Benslimani Abderrahmane
Published: February 2023

More wells are being completed with fiberglass casings to overcome the challenge of corrosion to the carbon steel casings. Fiberglass casing is expected to increase the longevity of the wells. The wells completed with fiberglass still require the operators to confirm that the casing is in good condition and also the annular cement sheath is able to provide mechanical support and zonal isolation. The evaluation poses a challenge as the properties of the fiberglass are very different to that of the carbon steel casing. Some studies were performed in 2018 to test the ultrasonic physics in fiberglass, this paper will describe the challenges and how we have now developed an innovative data acquisition, processing and interpretation workflow to properly evaluate both the fiberglass casing condition and as well the annular cement condition.

It was observed through surface experiments that the conventional ultrasonic technique applicable to carbon steel pipes has been proven to be invalid in fiberglass casings because the velocity and acoustic impedance of fiberglass are much lower than steel; therefore, there is no resonance in fiberglass. A new interpretation workflow was developed and applied to raw data to build specific parameters proper to the fiberglass samples to determine the acoustic properties: acoustic impedance, attenuation factor and velocity. It is for the first time that data has been acquired in a very large fiberglass casing.

Fiberglass casings were run in water well, and wireline acoustic logs were successfully acquired for cement and corrosion evaluation across 19-inch. OD Glass Reinforced Epoxy pipes. The interpretation workflow was applied to raw field data and a comprehensive cement map and corrosion answer products were obtained with an acceptable quality control level. The paper will review the data from three wells.

This innovative data acquisition, processing, and interpretation workflow can be deployed in wells for decision making prior to completion and production. The new method also opens up future opportunities for the evaluation of non-carbon steel pipes, and with knowledge of mechanical and acoustic properties, the method can be adapted to perform a full evaluation. This method is expected to provide valuable information for wells planned to be completed with fiberglass casing.
Floating Structure Integrity Management Program (FSIMP) Towards Digitalization
Authors: Tong Wen Jie , Kar Suman , Bin Taib Hasmi , Bin Abdul Rahman Azam
Published: February 2023

The objective of the paper is to demonstrate digitalization of Floating Structures Integrity Management Program (FSIMP) and its application for the structural integrity of floating structure assets. The framework of FSIMP is being developed by adopting Risk Based Inspection (RBI) methodology and complemented with technical know-how and industry best-practices. Implementing the methodology provides strategic planning for maintenance by reducing the anticipated risk. Hence, ensuring uninterrupted service of the floating structure assets throughout the service life.

This paper presents a systematic approach for digitalization of the integrity management program for a nominated floating structure asset. The methodology offers a procedure to acquire necessary data management gathering, risk assessment, and RBI survey plan to maintain the structural integrity in the centralized web-based platform of FSIMP. RBI process is adopted into the FSIMP to investigate all deterioration and failure mechanisms. These structures will be identified by qualitative and quantitative risk assessment methods.

The implementation of FSIMP offers a wide range of capabilities in structural integrity management such as integrating all floating structure fleet assets in a single dashboard of web-based platform, clear line of sight for reliable structural integrity, and an holistic overview across all levels of management. FSIMP with RBI methodology evaluates all data gathering to optimize inspection resources based on the risk assessment through an optimum combination of inspection methods and frequencies. The whole process is aligned to the requirements from Classification to ensure reliability for continuous operations. It also observes the essential need of digitalization for FSIMP during the time of post-COVID19 pandemic and the ever-expanding offshore oil, gas and energy frontiers that demand the adoption of new and advanced technologies, especially in the field of digitalization. It is shown that FSIMP has great potential as a digitalization tool and system to integrate with the RBI risk assessment that aligns to the requirements from Classification. It is strategically to maximize the effectiveness and improved efficiency for inspection and monitoring plan.

The paper provides information on the solution of digitalization to the Floating Structures Integrity Management Program (FSIMP) in ensuring that the integrity of floating structure asset during the service life is intact for continuous operation and a holistic overview for all the assigned fleet assets in a centralized dashboard web-based platform. In addition to that, RBI is as added benefit to the FSIMP with its structure methodology of data evaluation and risk assessment in order to objectively optimizing inspection and maintenance resources.
Advancement in Waterflood and EOR Performance Assessment and Optimization with Capacitance-Resistance Model in the Largest Oil Field, Thailand
Authors: Laochamroonvorapongse Rapheephan
Published: February 2023

The main mechanism of waterflooding and enhanced oil recovery (EOR) is oil displacement by injected fluid; however, complexity in the geological system, limited understanding of interwell connectivity, vertical heterogeneity, and lack of injection and production controls lead to lower-than-expected flood performance. This study is aimed to assess and optimize the ongoing waterflood and polymer flooding performance in a mature S1 oil field in Thailand.

The capacitance resistance model (CRM) is a physics-based reservoir model that derives interwell connectivity and reservoir properties solely from the input of production, injection, and pressure data. In this study, the rigorous workflow of CRM model coupled with fractional flow model was built by using Python language to dynamically perform the reservoir analysis focusing on the polymer pilot and mature waterflood areas. The reservoir connectivity map and reservoir properties were obtained from the CRM model matching, and the flood optimization plan was the output after coupling those two models.

The CRM model provides good fittings of well production rates in case there is sufficient production data and the derived interwell connectivity is in good agreement with the interwell tracer results, the regional sedimentary supply direction, and waterflood analysis by reservoir engineers. The input of bottomhole pressure data from electric submersible pump (ESP) sensors can enhance the quality of CRM fittings, especially when reservoir is in the under-injection state. For the optimization study, well injection rates were adjusted with the objective function to maximize oil reserves, and the results signified a total incremental oil gain of 1 MMSTB approximately. The recommended waterflood optimization plan was implemented and is being evaluated in the field.

The integrated CRM workflow could replace the 3D-conventional reservoir simulation model where it may contain high uncertainty of geological structures and characteristics. The CRM also enables the intensive waterflood and EOR assessment as well as flood performance optimization. This application would be a key to ensuring the success of the waterflood and EOR journey.
Sensitivity Analysis and Cost Analysis for Casing Designs (Case study)
Authors: Abbood Husam Raad Abbood , Alkamil Ethar Khalil , Miftah Karrar Riyad Miftah , Al Dhaheri Amgad Hamad Khalaf , Al Luaibi Ibrahim Salim Abdullah , Almaarij Muhammed Adnan Khudhaier , Alhilfi Ali Hassan Jaber , Hamad Zamzam Neama Hamad
Published: February 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.