bluuebunny/crossref_metadata_2025_split huggingface dataset:
A Novel Approach to Analyze Fracture Properties Utilizing Advanced Mud Logging
Authors: Qatari Ammar , Qubaisi Khalid , Dsouza Steve , Magnier Caroline 
Published: August 2022

Abstract
Mud logging, in essence, is a wellsite operation that investigates, records, and analyzes measurements obtained from the circulating drilling fluid that results in the measurement of cuttings and gas. It plays a vital role in the identification of downhole geological conditions, such as hydrocarbon presence and stratigraphy along with monitoring drilling conditions, to ensure safety of operations and improve efficiency. The objective of this paper is to utilize advanced mud logging analysis characteristics to establish a workflow to potentially identify fractures along an interval. Helium is used as the correlation parameter to potentially indicate fractures along the intended formation. Advanced mud logging provides a quantitative hydrocarbon measurement from the drilling mud rather than the qualitative measurements that regular mudlogging provides. Helium is one of the major components that advanced mudlogging provides and acts as an indicator of permeability in a formation. The process starts with a novel method to utilize helium to be a correlator of fractures within a formation in terms of identification and measurements along with tracking the fracture with time. The combination between current formation imaging procedures and helium readings from mud logs is proven to be a key potential indicator to establish a fracture identification pattern.
The utility of the correlated helium readings from mud logging and fractures from formation image logs is a major breakthrough into identifying formation fracture features. Tracking changes of such features in which mud logging readings are used directly as potential indicators of fractures in an anticipated well. Loss of circulation prediction and LCM designs are enhanced directly by this extra knowledge.
Pragmatic Strategy for Operational and Cost Efficiency Improvement: A Case Study of Rig Selection Strategy for Hydraulic Fracturing Operation in S1 Oil Field Thailand
Authors: Sirirattanachatchawan Thum , Kanjanarat Sukrit , Pirom Pavin , Siriphruek Kanwisa , Tantianon Anan , Nadoon Apiwat , Follett Meth , Paramart Chatchai , Kukiattikoon Arisara 
Published: August 2022

Abstract
This paper aims to elaborate the strategy for operational and cost efficiency improvement by providing an example of a successful case of rig selection strategy for Hydraulic Fracturing Operation in S1 oil field Thailand. The integrated workflow proposed involves all concerned parties to specify the scope of work, analyze internal and external strengths and weaknesses, evaluate possible scenarios, and identify the procurement strategy. As a case of rig selection for fracturing operation in the heterogeneous sandstone, committing the number of candidates before drilling is impossible. Therefore, the typical criteria for fracturing rig selection consider rig move mobility and flexibility in candidate selection. However, in a proven area, the uncertainty of candidate confirmation is manageable. Reservoir engineers provide the number of candidates in 3 scenarios for sensitivity analysis. SWOT analysis and the market survey reveal the possibility to improve both performance and cost by using a warm-stack skidding rig instead of a truck-mounted rig. The sensitivity analysis by using the historical data of each type, indicates that the number of candidates and rig cost play a significant role in cost saving. As a result of analysis and strategy, the operation performance improvesby 34% (2 months reduction) leading to cost-saving by 1MM USD or 24% of the time-dependent cost.
Development of Early Oil Well Cement Properties Using Laponite Particles
Authors: Ahmed Abdulmalek , Mahmoud Ahmed Abdulhamid , Elkatatny Salaheldin 
Published: August 2022

Abstract
The cement sheath is exposed to several loadings, which can possibly harm its key properties and impede its functions. These loadings become more significant at the early age of forming the cement sheath in which the properties of the cement are not completely developed. The objective of this work is to evaluate the changes in the cement matrix properties at the early stages of the hydration process for the cement containing laponite particles and compare it with the base cement. Laponite is a natural inorganic source containing mainly silicate. It is used as an additive to modify and enhance the rheological properties of many products.
Several cement samples with and without laponite were prepared and evaluated at four different curing times of 12, 24, 48, and 72 hours. Several cement properties such as porosity, Young's modulus, density variation and compressive strength were evaluated at each time. The results showed that the porosity of both cement samples increased with curing time, and the addition of laponite decreased the porosity of the cement samples. The addition of laponite particles also improves the elasticity of the cement as indicated by the decrease in Young's modulus. The early density variation of the cement was minimized when the laponite is used. The results of compressive strength indicated that the compressive strength of both cement systems increased with the increase of the curing time and the laponite-based sample had higher strength than base cement.
Stiff String Torque and Drag: Choosing a Realistic Tortuosity Model
Authors: Nobbs Benjamin , Plee Christophe , Dao Ngoc-Ha 
Published: August 2022

Abstract
Selection of the correct tortuosity model is critical when performing a pre-planning stiff string torque and drag analysis. Various tortuosity models exist in the literature however selection and calibration can be complicated. This paper presents a methodology to aid in selecting an appropriate tortuosity model as well as real case studies.
The goal is to apply a suitable tortuosity to a planned trajectory that will mimic the expected tortuosity along the wellbore. Depending on the directional drilling driving system employed, the trajectory can be smooth or very tortuous with significant additional local doglegs. Overall, the effect of standard tortuosity models on a run-in-hole (RIH) analysis using a stiff string torque and drag model will be investigated. Industry standard tortuosity models such as sinusoidal, random, random with dependent azimuth and helical will be investigated to help identify when they are appropriate depending on the directional driving system employed.
In today's high-cost and complex 3D wells, simulations using smooth planned trajectories together with conventional soft-string torque and drag models have shown its limits in anticipating bottom hole assembly (BHA), casing or completion strings lock-up events. Hence, new methodology shall be introduced to better predict field observations. This methodology shows that the applicable tortuosity model may change depending on the directional driving system used. The drilled path or a motor, with a slide-rotate pattern, may be significantly different to that of the cyclical path drilled by a rotary steerable system (RSS). The case study shows that the additional tortuosity that was generated by the directional driving system had a significant effect on predicted hookload margin as well as elevated forces and stresses along the liner. The stiff string torque and drag and buckling model can analytically calculate the contact points which may vary significantly, both axially and radially, in a tortuous wellbore. Ultimately the selection and calibration of an applicable tortuosity model is necessary when performing a robust stiff string torque and drag analysis.
This ability to correctly apply a tortuosity model in preplanning reduces the risk of BHA, casing and/or completion strings getting stuck or locked-up when running in hole, paving the way for a reduction in non-productive time (NPT) and loss of equipment.
The Use of an Organic Crosslinked Polymer Sealant as a Barrier to Retrieve Stuck Coiled Tubing from a Live High Pressure Well After Over a Year: Case Study from Offshore Vietnam
Authors: Daohmareeyor Tuanangkoon , Wei Lock Deric Leong , Wattanasuwan Reawat 
Published: August 2022

Abstract
Coiled Tubing (CT) is a commonly used well intervention technique for sand/debris cleanout, milling, fishing, cementing, and gas lifting applications. Performing cement plug operations with CT in high-pressure live wells can present a relatively high level of risk of getting stuck, improper placement of cement plugs, and poor quality cement plugs. In this scenario, an offshore well in Vietnam was left with CT held only on the surface by the Blow Out Preventers (BOP) after getting stuck downhole more than a year previously. Retrieval of the CT was required without any downhole barrier in place and circumstances that made the conventional killing of the well difficult. This paper will discuss the equipment necessary, factors to consider in the job design, sealant design with lab testing, and describe the technique used to safely retrieve the fish from the well.
During the design phase of the solution, risk assessments were carried out to cover various scenarios such as:
Poor condition of one or more of the CT string, BOP, dual ball kelly cock valve, double flapper check valve. Inability of the Organic Crosslinked Polymer sealant to hold well pressure. Difficulty in latching the surface CT stump, and the potential requirement for freezing to establish a surface barrier.
Along with the specially designed sealant treatment, multiple yard tests for dressing the sheared CT and latching were performed to represent actual conditions during the operation and allow risk mitigation plans to be put in place.
Firstly, the barrier verification process was performed to monitor any well pressure build-up from the downhole/surface pressure reading to confirm a barrier was in place, allowing surface equipment to be rigged up. After this was confirmed, the equipment was rigged up, and a fluid circulation test followed by the inflow test of the double flapper check valve in the bottom hole assembly was performed to verify CT integrity. The first of the organic crosslinked polymer was then pumped to plug inside the CT before electric line (E-line) was run into the CT to cut at the free-point above the stuck location. The second organic crosslinked polymer was then placed to plug between the CT and annulus, forming a barrier allowing the makeup of the spoolable connector. Finally, retrieval of the 1,700 meters of CT string took place without any loss of well control.
Retrieving the CT from this high pressure well presented a lot of challenges. Achieving a safe and successful operation showed that with proper planning, design, and risk mitigation plans, a potential well control situation can be prevented with the well being secured and successfully returned to production. This paper can now serve as a guideline for future operations with similar circumstances requiring retrieval of stuck CT from high-pressure wells where it has been held on surface for an extended period of time.
Conceptual Casing Design for a HPHT Carbonate Development Project with High CO2 and H2S Contaminants
Authors: Ong Swee Hong Gary , Ungku Hamzah Ungku Syafena , Manson James , Abdul Razak Ahmad Hakam , Umar Lawrence , Kongpat Nitipong , Grant Colin William Graham , Wejwittayaklung Kittipat , Konganuntragul Pornchuda , Piyakunkiat Nuttapon , Abdul Rashid Khairul , Toempromraj Wararit , Chanpen Chakrit , Bandyopadhyay Parthasarathi , Bin Hamdan Mohamad Kamal , Jantasuwanna Prapaporn 
Published: August 2022

Abstract
HPHT wells are typically associated with high complexity, technically challenging, long duration, high risk and high NPT as many things could go wrong especially when any of the critical nitty-gritty details are overlooked. The complexity of this project is amplified with very high level of contaminants compounded by high pressure and high temperature environment.
In the conceptual planning phase for the upcoming development of such project where its scale and severity are unprecedented in the country/region, a fit for purpose casing and tubing design is critically important to ensure the well integrity over its design life is assured. At the same time, cost optimization can be achieved utilizing industry practices, testing and qualification of materials and vast learning from incidents and failures occurred in similar HPHT projects over the last three decades scattered around the world.
This paper intends to outline the challenges and optimization of casing design philosophy which is drawn upon various perspectives such as long term well integrity, drilling operations, working stress design, effect of compaction and subsidence, probability of failure analysis, multi-well thermal analysis, downhole material corrosion performance, connection performance and a combination of all the above in a holistic manner.
A particular focus would be discussing the delicate balancing act between satisfying the working stress design of downhole tubular versus the complexity of downhole material selection work. With the given challenging environmental condition, this points towards exotic type of CRA materials which require certain magnitude of yield strength deration attributed to the given environmental condition and their respective manufacturing processes.
A New Fracture Network Swept Volume Prediction Approach for Multi-Fractured Horizontal Wells in Shale Oil Reservoirs
Authors: Tao Liang , Kang Ning , Hu Kejian , Deng Xianan , Halifu Mirinuer , Zhao Yuhang 
Published: August 2022

Abstract
The continental shale oil reservoirs usually have strong heterogeneity, which make the law of fracture propagation extremely complex, and the quantitative characterization of fracture network swept volume brings great challenges. In this paper, firstly, the facture shape of volume fracture is described preliminarily. Secondly, the volume fitting model of seam mesh transformation was established by coupling the key geological engineering parameters by multiple nonlinear regression method, and the productivity numerical simulation method was used to correct the reconstruction volume. Finally, a new concept of fracture network swept coefficient is put forward to quantitatively evaluate the fracturing effect. The study results shown that fractures created during the volume fracturing of shale oil reservoir appear as a belt network made up of main fractures primarily and branch fractures secondarily in the shape of cactus, and the main factors affecting the fracture network swept volume are fracturing fluid volume, fracture density, brittleness index, pump rate, horizontal stress difference, net pay thicknessand proppant amount. The prediction method is verified by the typical platform in the field to be accurate and reliable. It can provide scientific basis for the evaluation of volume fracturing effect of horizontal wells in shale oil reservoirs.
First Experience Matter: The Valuable and Great Learnings from Unfavorable Mud Acid Stimulation in S Field Gravel Pack Wells, East Malaysia
Authors: Bakar Hasmizah , Ravichandran Narindran , Hassan Hamidah , Abu Bakar Mohamad , Idris Khairul Nizam , Masoudi Rahim 
Published: August 2022

Abstract
Most of the S oil field producers experienced rapid decline in production and this is suspected due to fine sediment particle migration and plugging. The S field team had carried out external formation damage study as they have no expertise and field experience to determine the damage mechanism and evaluate the best acid treatment recipe for their formation damage. Recently, mixtures of traditional hydrochloric and hydrofluoric acids have been used for the removal of near-wellbore damage in S field sandstone formations. The stimulation campaign in this field which has turbidite reservoir, high clay content predominantly by kaolinite and illite with high siderite mineralogy applied both bullheading and coiled tubing squeezing techniques. The treating fluid selection is highly dependent on mineralogical data and laboratory works. Based on the core flood testing performed, high strength mud acid is chosen as the main treatment fluid and gave superior result in permeability recovery as compared to milder organic acid and HF. Unfortunately, the actual field stimulation turned out to be opposite from the core flood testing outcomes. The situation is worsened in multistage treatments, which traditionally involve many repeat stages of preflush, main treatment, overflush and diverter. The mud acid stimulation prompted more water production and fine migration that is ended up with production curtailment. Only one out of four of the treated candidates resulted significant gain after gas lift valve change took place. This paper also will outline the reviews on results of laboratory testing and field actual performance together with the recommendations for future improvement. Stringent candidate selection, improved treatment fluids cocktail, operational challenges such as unanticipated longer flow back period, post treatment unwanted precipitation, ineffective diverter placement and skin build up post treatment are among of the learning points captured in this paper. From this unfavorable mud acid stimulation campaign which cost USD4million value leakage, our team comes out with best practices for future stimulation and key learning to share with industry colleagues who has no field background to combat with fine migration issue in their sandstone asset. Laboratory works is not the only paramount to any stimulation, success in stimulation is a journey, not a destination. The doing is often more important than the outcome.
Successful Application of Fishable and Sectional ESS Completion Technology for Sand Control _ A Case History in SHAD Field
Authors: Zhang Lina , Zhang Heng , Hu Jintong , Zhang Songjie , Yang Wenling , Yang Changlu , Yu Xueliang , Hao Yuhong , Wang Bin 
Published: August 2022

Abstract
SHAD oilfield, located in one of the fields with the highest onshore production in the Middle East; more than 70% of its production wells are flowing wells, with an average single well production capacity of more than 3000 bbl/d. Its main oil production formation is loose sandstone reservoir. The completion style of its production wells are generally completed casing perforation, and sand production is obvious after a period of exploitation. In the process of production, sand cleaning and sand discharging are often needed in the perforated section of oil well; however, after 3-5 years of production, serious sand burial still forces developers to give up the original production formation. In addition to the problem of sand production, there are many complex layers, some of them are oil-water layer, and the increase of water in the liquid production gradually affects the well flowing.
Fishable and sectional expandable sand screen (ESS) completion technology is developed to deal with sand production and the increase of water production. The upper of the original production formation of the old wells is as the new production formation. The new formation is divided into several sections due to different physical properties. Perforation is carried out at the same time for all sections. After this, each the ESS completion string is run into each section. The top sealing hanger and the bottom packer will seal each ends of the annular between ESS and perforating casing, thus to form independent production section. In later process of production, plugging tools is run for sections if needed, so as to realize selective open/ close of different sections. Special fishing tools are developed, combined with the mechanical plastic characteristics of ESS, which can realize the fishing of the completion string. This solves the problem of fishing long string, and provides good conditions for subsequent operations.
The research results show that two good results are obtained. One is that arranging several sections of ESS completion strings in the old well bore gives full play to the characteristics of ESS with strong flow capacity, good sand control effect, and is suitable for sand control in high-yield wells. The other is that selective open/close is realized for different sections which meets the sand control and production needs of in SHAD oilfield.
The research results have applied to 9 wells in SHAD oilfield, and the success rate is 100%. Among them, one single well is divided into three sections, and the production is stable, the sand production is near to 0, and the sand control effect is significant. The successful application of this technology fills up the gap of multi-stage ESS completion in the Middle East.
The First Application of a Coiled Tubing Catenary System in the Gulf of Thailand. A Technology Break Through for Offshore Facilities with Space and Weight Limitations
Authors: Uasetwattana Jantima , Kanchiak Surachai , Kornkitsuwan Chaichana , Saekoo Wijitra , Kitcharoen Tanyawadee , Wattanasuwankorn Reawat , Jiemsawat Nophadol , Toh Yea Lee , Azizan Yusri 
Published: August 2022

Abstract
Coiled Tubing (CT) catenary technology supports the possibility of executing offshore interventions on platforms with space and weight limitations. Having the majority of the CT equipment remain on a separate support vessel vastly increases the platform working area and minimizes offshore heavy lifting. The system allows the operation of well control and pumping equipment from the vessel for a single control source and an overall faster, safer, lower-cost operation.
Limited offshore platform space and crane capacity are a significant concern for intervention operations in the Gulf of Thailand. A conventional CT unit is simply unable to fit on a small offshore facility. The catenary system was introduced to eliminate these limitations by keeping the main CT equipment on the vessel while providing the connection and interface between the vessel and platform equipment, allowing a safe and efficient operation. It also has the flexibility to enable the vessel to adjust its location during bad weather if required, without affecting the overall safety of the operation. The same system can also be used on regular platforms without space and weight limitations during the same campaign.
The catenary system saved two days per well, resulting in savings due to less equipment utilization, reduced personnel, and accommodation requirements, and reduced consumables used. Less heavy lifts also saved time, associated costs, and increased safety during the preparation phase. The CT operator can also load the maximum length of CT pipe onto the vessel without concerns about having to join multiple strings or using split reel spooler equipment. All well control equipment was function tested and operated as standard with real-time monitoring and capturing of well conditions, operation parameters, and CT fatigue the same as expected from a conventional CT setup. The paper will elaborate on the catenary principles, concepts, and engineering background for these types of operations.
The CT catenary was proven to bring significant efficiency improvements, safety enhancements, and faster operations, leading to cost-saving when carrying out CT interventions in the Gulf of Thailand. The techniques and details will be elaborated on in the paper.