bluuebunny/crossref_metadata_2025_split huggingface dataset:
Striving Towards Zero Gas Emission
Authors: Ariffin Mohd Hafizi , Guillory Ryan , Low Bee Chan , Salleh Fairus Azwardy 
Published: March 2022

Abstract
Greenhouse gas emission (GHG) is the main contributor to global warming, so the industry players need to take a huge step to reduce GHG. Furthermore, the implementation of carbon tax has eroded oil project values and drives teams to think about ways to reduce the carbon tax.
This paper highlights the subsurface studies, gas balancing method, and surface modification effort to reduce the gas emission in Field B while reaping the benefits not just of reduced carbon tax but increased oil production and revenue.
Gas injection is not just increasing reservoir pressure but also reduces emission. Several reservoirs in the field have been depleted by 66% to 500 psi. The team converted the existing oil wells to gas injection wells instead of spending high CAPEX to drill new gas injection well. This way the team can confirm the benefit of gas injection with a low-risk cash injection.
The field has a high amount of unproduced Non-Associated Gas (NAG), but this NAG cannot be produced without a gas evacuation plan. Producing the NAG will cause the field to vent higher with existing facilities installations. So, the team came out with a plan to monetize the gas by installing a new gas pipeline and new gas processing platform. Furthermore, the Associated Gas (AG) which was vented previously can be channeled to the new compression system to further reduce the emission.
Currently, the gas from the surge tank is lined up straight to the vent stack. A Vapour Recovery Unit (VRU) was proposed to install upstream of the surge vessels. The VRU will pump the gas back to an AG gas compressor and straight to the gas sales line.
The gas injection project has increased the reservoir pressure from 500 psi to 700 psi. As a result, one idle well reactivated to produce oil, two wells were drilled from the same reservoir, and gas venting was reduced by up to 7 MMscf/d. Because of this success, several other wells were identified for gas injection candidates in other reservoirs.
NAG gas project is expected to provide 100 MMscf/d revenue. In addition to that, the NAG project also helps to reduce AG venting because of AG compressor limitations. The additional AG volumes are around 5 MMscf/d.
VRU installation is still undergoing doability and commerciality study because the gas from the surge vessel is minimal. However, the team's dream towards zero gas emission is a step closer if VRU installation is brought forward.
Because the field is not well equipped with a gas meter for each piece of equipment. An accurate and understanding of gas balance estimation is important to drive zero gas emission.
Surface Casing Collapse Load Design Optimization Challenges for Highly Depleted Reservoir
Authors: Yap Yun Thiam , Wahi Wahidullah , Campbell Scott 
Published: March 2022

AbstractIn the current climate, cost reduction has been a major enabler for project sanction. With significant drilling activity planned in relatively benign environments offshore Malaysia, there were potential casing design optimisations, and hence cost reduction opportunities, in analyzing the relevant well planning data of such projects, with a view to further optimising the standardised 13-3/8" surface casing specifications that have historically been used in similar areas. Additionally, the feasibility of using 13-3/8" casing as slim conductor on platform development wells was investigated.Well planning data for a variety of projects planned for between 2022 and 2024, which planned to use the same 13-3/8" surface casing specification, were collated and boundary conditions were established for all of the key parameters. This standardised casing string was first assessed for suitability, and areas for potential optimisation were identified. Simplified casing load analyses optimisation were performed on this optimised 13-3/8" casing specification for typical collapse loads as laid out in the company's casing design standards, to assess its suitability. Generalized fatigue life analyses were also performed on the slim 13-3/8" conductor to try to prove viability of the concept.It was shown that collapse design is the controlling factor for the cost reduction initiatives through 13-3/8" casing specification optimization, especially in an environment of severely depleted reservoir (down to 3 ppg) in the reservoir section underneath the surface casing. This is exaggerated with conservative load assumptions that is used in the industry/company standards i.e., running mud weight, 50% to 100% evacuation, extreme low pore pressure assumption as low case prognosis etc. Combination of conservative collapse prohibited the casing specification to be optimized lower.This paper addresses the 13-3/8" casing optimization through fit for purpose collapse design approach. It was shown that the reduction of the casing specification for 13-3/8" surface casing in the majority of the projects studied was justified and acceptable based on the minimum design requirements for collapse loads. Additionally, cost savings of up to approximately 7% were observed for this reduction in 13-3/8" surface casing specification depending on connection qualification and casing manufacturer.
Building a Sustainable Life Cycle Cost Efficiency Model
Authors: Kusumawardhani Mayang , Arnhus Magnus Soon , Markeset Tore 
Published: March 2022

Abstract
Life cycle cost (LCC) evaluation has been a powerful decision-making support tool for assessing different alternatives throughout an asset's life cycle. After having been ushered in by the global awakening of a sustainability conscience, there is a need to upgrade the LCC calculation to include these sustainability factors. This train of thought has also been acknowledged by the oil and gas industry, through the recent update of the ISO 15663:2021 (International Organization for Standardization), which addressed sustainability, in conjunction with other ISO standards, guides and the IOGP (International Association of Oil & Gas Producers) report.
Following this trend, the paper aims to present a sustainable LCC efficiency model for oil and gas facilities, particularly in the selection of the optimum equipment or package. To achieve this, the paper drilled down possible cost factors related to these concerns and offers a model that is required to remain relevant in the current conditions.
The LCC model presented was developed through a systematic research method, including trials, feedback loops and validation processes. Potential production risks were also factored in, so that the LCC would deliver the best possible value to the business. Finally, a step-by-step process in developing the LCC structure will be illustrated and explained in the paper.
The Role of Mooring Line Monitoring in an Effective Asset Integrity Management of Floating Wind Farm
Authors: Sha Yong , Feng Wei , Zhang Hui , Lim Frank , Natarajan Shreenaath 
Published: March 2022

Abstract
As offshore wind farm developments move into water depth above 60m, one of the greatest challenges is in designing cost-effective mooring systems capable of overcoming the added risks of more severe environments, complicated floating structure response, and turbine forces. The failure of a primary mooring component could lead to unacceptable consequences, including destruction or complete loss of assets, loss of continuous electricity generation, possible retrieval of destructed structure, and possible injury or loss of human life during maintenance. It is essential to ensure that mooring systems operate without failure.
Operators have recognized the importance of installing instrumentation such as GPS to monitor floating wind structure location. However, motion monitoring instruments have seldom been deployed on mooring lines of floating wind farm structures to capture dynamic response, which will govern the integrity of the mooring system and subsequently the whole floating wind structure. Measured data from these instruments on mooring lines allow an operator to determine when the limits of acceptable response, predicted by design analysis or scale model tests, could be exceeded in terms of strength and fatigue.
This paper describes the role of mooring line monitoring in an effective asset integrity management of floating wind farm and provide a typical procedure for the development of a fit-for-purpose mooring line monitoring program. Furthermore, this paper presents an advanced monitoring method to capture the dynamic response of the mooring line by a cost-effective and maintainable solution.
Casing and Cement Evaluation on Drillpipe: New Tool Acquires Well Integrity Data in Parallel with Existing Drillpipe Deplyed Operations from Drilling to Plug and Abandonment
Authors: Hawthorn Andrew , Steinsiek Roger , Rahman Shaela 
Published: March 2022

Abstract
Casing and cement evaluation logging has long been essential for the success and safety of well operations from spud all the way through to abandonment. Indeed, as the casing and subsequent cement play such a critical role in the separation of fluids and the provision of downhole pressure barriers it is essential and sometimes also a regulatory requirement to obtain such data. For example, understanding the condition of the casing, whether it is worn or corroded, and the material in the annulus behind the casing, such as cement, fluid, formation or even gas directly plays into the success or otherwise and also the safety of multiple well operations. Historically this information has only been available from wireline conveyed tools. As a consequence of this other rig operations then have to stop to allow the wireline logging. It is also true to say that over the last few decades wells have become significantly more complex, more deviated and deeper. In addition, the pressure regimes have required tighter margins increasing the risk of operations and necessitating a greater need to understand the integrity of casing and cement barriers. As the wells have become deeper, more complex and more highly deviated it is also more difficult to run wireline conveyed tools, often significantly increasing the amount of time required to run and obtain this data. In fact, it can be clearly seen that increasingly, operators have often declined to get this critical data due to the time and effort required in certain circumstances to log on wireline. This has had a significant impact in terms of non productive time associated with not understanding the condition of casing and cement in well operations such as side tracking or cut and pull operations.
For those associated with drilling then there has been a huge advancement in the technology, reliability and utilization of logging while drilling technology, although this has traditionally been employed in the openhole sections and deployed only while drilling. This paper will introduce a drillpipe conveyed casing and cement evaluation tool that can be deployed in parallel with other runs in the well to improve the efficiency of operations whilst also increasing the frequency of times that this data can be acquired. Through case history we will demonstrate how operators improved efficiency, reduced rigtime and personnel on board, improved the safety of operations and reduced the risk of non-productive time by the application of this new drillpipe conveyed technology.
First Experience Matters: Evaluation of Acid Treatment Recipe for Fines Migration Control in S Field Sandstone Reservoirs
Authors: Bakar Hasmizah , Ravichandran Narindran , Abu Bakar Mohamad , Idris Khairul Nizam , Masoudi Rahim 
Published: March 2022

Abstract
Restoring formation damage by acid matrix treatment in sandstone formations faces multiple challenges due to variable petrophysical and compositional properties. The S field team had carried out a formation damage study to determine the damage mechanism, evaluate the best acid treatment recipe to treat the formation damage mechanism identified and study the effect on petrophysical properties before and after the treatment. Most of the S field oil producers experienced rapid decline in production, and this is suspected to be due to fines migration and plugging.
The formation damage study is divided into three sections: the field background review, the potential formation damage identification, and the evaluation of the best acid treatment recipe for S field formations. Core samples from a wide range of mineralogy, permeability, pore distributions and porosity were evaluated using laboratory testing to describe the elemental and morphological presence of each mineral. Then, four of the core samples were high graded for evaluating the permeability by flooding with brine and oil to examine the fines migration and dispersion potential of clays and siderite. The next phase of this study was continued with the core sample acidization using organic acid and HCl to identify a suitable acid treatment cocktail. This will be discussed in detail in this paper.
Fines migration was observed to be resulted from movement of both siderite and aluminosilicate clays under representative conditions. The evidence from the geological analyses and core flooding shows that in brine, there is a tendency for siderite to migrate, potentially even at low flow rates. The effect is expected to be more severe in brine than in oil and possibly in both phases. HCl acid and strong organic acid treatments with and without the presence of an iron control to remove iron carbonates in siderites and iron-silicate gel formation will be outlined in this paper. The result of the HCl treatment was that it was able to remove carbonate material from the core, but it was still not able to substantially improve wellbore permeability. An additional short phase of testing examining a HF-HCl package was demonstrated more effective and is discussed extensively in this paper.
This laboratory work is not unusual to the sandstone stimulation however the discussion of the core flood testing findings and acid recipe comparative study provides more comprehensive understanding on the effect of fines migration to the success of the stimulation treatment and its effect on petrophysical properties. The outcome of this work will lead to a reliable design of sandstone matrix acid treatments and, increase the acid stimulation treatment success rate which subsequently optimizes well productivity.
Field X, Central Luconia, Offshore Sarawak, Malaysia, Early Appraisal Stage Reservoir Characterization
Authors: Poret Kelly , Saller Art , Henglai Puntira , Laitrakull Kasira , Chongrueanglap Pongsit , Siriwattanakajorn Warintaphat , Chris Platt 
Published: March 2022

Abstract
Miocene carbonates have been producing gas in Central Luconia for more than 30 years (Warrlich et al., 2019). Approximately 65 TCF of recoverable gas have been discovered to date in these build-ups (Scherer, 1980; Mahmud and Saleh, 1999; Khazali et al., 2013; Kosa et al., 2015; Warrlich et al., 2019). One of the most recent carbonate discoveries in this region, Field X, is in its early-stage of reservoir characterization. Depositional and facies models have been created with newly acquired data from LL-C appraisal well.
Tectonics, accommodation, and sea level contributed to the overall shape and deposition of the carbonate buildup. One appraisal well, LL-C was drilled and penetrated a thick carbonate section on the structure. With the available data, facies and conceptual depositional models were created using well logs, sidewall cores, conventional cores, cuttings, seismic, and an extensive literature review. At the time of this study, core laboratory analyses were not yet completed. The reservoir is separated into five zones based on well log, core, and seismic data. A precursory facies model was completed using only photographs from the sidewall cores acquired in all five zones of the structure and photographs from conventional core acquired in the upper reservoir interval. Five facies were identified: Coral, Packstone, Wackestone, Mudstone, and Cemented Margin. The data acquired in LL-C illustrates the complexity of carbonate reservoirs and the need to acquire core early in the appraisal of carbonate reservoirs.
Carbon Footprint Assessment for Decarbonisation Strategy Development
Authors: Jamal Hisne Fairul Izmal , Hughes Kayleigh Dawn , Su Li Yuen 
Published: March 2022

Abstract
As reported by the United Nations Framework Convention on Climate Change (UNFCCC), the quantity of atmospheric Greenhouse Gas (GHG) concentrations in the atmosphere has elevated by an average of 1.6% annually over the last three decades, primarily contributed by carbon dioxide gas (CO2), and is currently considered to be one of the top three issues facing the world today. Climate change, as a result of increased GHG concentrations are threatening adverse impacts to the natural environment, as well as human livelihood and survival. In response, international actions, such as the Kyoto Protocol 2005 and the Paris Agreement 2015, gathered nations worldwide to set targets with the intention of mitigating climate change and reducing its impacts. One such action is the movement towards ‘net zero’ CO2 emissions to be achieved by 2050. A commitment considered necessary by the Intergovernmental Panel on Climate Change (IPCC) for realising the goal of global temperature stabilisation to 1.5 °C above pre-industrial levels.
Increasing environmental, consumer and regulatory pressures, have driven the need for transitions in business focus towards sustainability by reducing overall GHG emission and carbon footprint. The integration of sustainability in business strategies is vital to avoid the occurrence of potential risks by demonstrating a clear link between the commitment to the sustainability agenda and continual business development. Undertaking a carbon footprint assessment of current and future assets is critical, to understand the nature of emission sources, and the contribution levels of each source to enable organizations to plan and make decisions which provide the most benefit in executing emission reduction strategies. The use of supporting tools developed in compliance with GHG Protocol principles, can provide clarity on carbon footprint drivers and enables informed, clear, traceable, carbon conscious, rapid decision making for business operations.
This paper will discuss how the application of digital tools allows for the development of baseline understanding of an organization’s carbon footprint. Further, the subsequent steps required in utilizing the baseline information to determine feasible carbon reduction strategies in a traceable, verifiable, and systematic manner, will also be explored.
Design of Mechanically Lined Pipe MLP for Lateral Buckle Zones – MLP Qualification and Calibrated Wrinkling Criteria Using FEA
Authors: Govindan Nampoothiri Sajith Kumar , Pawar Dipak , Mak Kok Wah 
Published: March 2022

Abstract
Mechanically Lined Pipe (MLP) is a pipe with a layer of corrosion resistant alloy (CRA) mechanically bonded to carbon steel pipe. MLP is mostly used in offshore pipelines for HPHT (high pressure and high temperature) conditions with corrosive contents. These type of pipe joints are largely used for HPHT offshore pipelines conveying corrosive fluids, but mostly limited to ‘non-buckle’ zones due to the concerns of liner wrinkling, fatigue damage and triple point failure resulting from high strain and stress ranges in the lateral buckle zones.
Recently, MLP's have been used for the entire length, including in the buckle zones of a dual HPHT multi-phase infield flowlines. Planned buckles have been designed at specific intervals to ensure controlled lateral buckling. Extensive qualification procedures are required to be undertaken to validate the use of these types of pipe at the buckle zones with high strains and stress ranges during repeated shut down cycles. The qualification procedure for MLP at the buckle zone are discussed in this paper. The paper also presents an optimized formula, calibrated based on the qualification procedure and Finite Element (FE) analysis for determining the optimized onset strain for liner wrinkling.
Initially, a thorough review of the concerns in the industry for employing MLP at the lateral buckle zone was undertaken and include the requirements for qualification/testing currently specified in the industry, such as bend test/liner wrinkling, and and full-scale fatigue tests.
Liner wrinkling is caused by excessive compressive strain that occurs during de-pressurisation of the flowline. To assess the risks of wrinkling, the compressive strain for the onset of liner wrinkling is evaluated using analytical calculations. This is followed by a comprehensive discussion on the qualification steps adopted for addressing the fatigue, triple point failure and wrinkle that enabled to use MLP at buckling and fatigue sensitive zones.
The qualification procedure undertaken has demonstrated better fatigue performance and wrinkling onset strains considerably higher than those evaluated analytically. The findings from the qualification and material tests are used to calibrate the ABAQUS FE analysis simulations to obtain optimised wrinkling onset criteria. An optimized wrinkling onset criteria for a range of D/t ratios defined based on Finite Element (FE) analysis results. In summary, this paper provides reliable guidance for the qualification of MLP at the lateral buckle zones. The paper also presents the methodology and results for determining an optimized strain for the onset of liner wrinkling based on ABAQUS FE analysis.
Defining the Optimum Well Completion for Marginal Field Development – An Approach
Authors: Syed Abd Rahim Syarifah Puteh Mariah , Azman Mohd Fairuz , Awang@Mohamed Zaidi , Ahmad Mior Yusni 
Published: March 2022

Abstract
Marginal field development commonly face setback when it comes to an investment decision, which makes it technically and commercially very challenging to be developed. Technologies that usually applied in big fields may not be economically relevant to the marginal fields, despite require the same assurance and functionality. Well completion cost itself can take up to 50% of the total well cost, especially for fields that potentially must deal with sand production, high CO2 and/or H2S content, artificial lift, and multilayer zonal completion and isolation. This paper demonstrates an integrated approach to identify and define the optimum well completion strategy for such conditions in a Malaysian oilfield.
The first step is to list all the operational issues and challenges of producing from the neighboring fault block and other analogue fields experience. Leveraging on the available data and types of completion that have been installed, a set of scoring is given to different completion type, considering the sand production control effectiveness, good well performance, and long well life span. The shortlisted completion types were further evaluated based on the following criteria:
Production flexibility Early monetization Operation complexity (drilling and completion) Sand production management Sand control failure probability Associated Risks Stand-alone economic
As a result, eight (8) completion strategies were investigated namely Monobore, Monobore wih resin, Cased & Perf, Cased & Perf with resin, Open Hole Stand Alone Screen (OHSAS), Cased-Hole Stand Alone Screen (CHSAS), Cased-Hole Gravel Pack (CHGP); using circulating method or frac pack. Different completion has its own advantages and disadvantages. Structured scoring system was again applied to guide the decision-making process. The key elements in the decision thought process are the associated cost of each option, the skin factor that affect the production and reserve estimation, and ultimately the Net Present Value (NPV) indicator.
In conclusion, identifying the optimum well completion will never give a single solution answer. However, the most important thing is to consider all the decisive factors and properly evaluate all options. In our own real example, the option that gives the best NPV coupled with tolerable risk (HSE risk i.e. less issue at surface) was selected as the optimum well completion strategy to be used in the development plan.