bluuebunny/crossref_metadata_2025_split huggingface dataset:
Breaking Records Using an Innovative Organophilic Clay-Free Invert Emulsion Fluid OCF-IEF to Drill the Longest Well to Date in the United Arab Emirates 35,800 ft
Authors: Nasrallah Mena , Vinci Matteo 
Published: October 2017

Abstract
This paper discusses the successful design, laboratory testing, and performance of an innovative, low solids, organophilic clay-free invert emulsion fluid (OCF-IEF) used to drill the reservoir section of an extended reach drilling (ERD) well. This specially designed drill-in fluid helped maintain the key ERD factors within the specifications necessary and set new limits for drilling performance, thus maximizing the horizontal section displacement/reservoir drainage and production output. ERD wells necessitate extensive design, planning, and close monitoring of various parameters to successfully complete the drilling and completion phases and deliver production expectations. While evaluating the feasibility of drilling the longest well in the UAE, establishing appropriate fluid system properties was a key focus area. The rheology profile was optimized for hydraulic management, hole cleaning, and fluid stability. The ground marble bridging package was designed to be minimally damaging. Lubricity and rate of penetration (ROP) maximization was also addressed by designing a low solids OCF-IEF in which the base brine was calcium bromide (CaBr2). This paper discusses the processes used during the planning phase, including laboratory testing and hydraulic simulations, and the procedures followed during the execution phase, which helped ensure trouble-free performance during drilling operations. Proper planning and execution using the best-available drilling practices helped enable the drilling of this record-breaking well, without significant issues that could impact rig time. The selection of an OCF-IEF to provide low equivalent circulating density (ECD) performance in a fragile gel fluid, with low sag risk, was fundamental to achieve the necessary fluid properties. The low solids design helped improve deployment of the weighting material (ground marble) compared to similar fields in which more conventional organophilic clay-based fluids were used. More than 18,000 ft were drilled in nine days with an average ROP of 2,000 ft/D, which set a record ROP in this field. As a result, the drilling operations were completed ahead of schedule and below the authorized financial expenditure (AFE). Additionally, the production rate was five times greater than estimated, thus confirming the anticipated nondamaging property of this OCF-IEF. The OCF-IEF design and performance brought within reach reserves not easily accessible using conventional mud systems and drilling techniques. The increased reservoir drainage resulted in significant productivity gains. This fluid can also be used during other operations to reach new target depths to maximize production.
Staying Ahead through Built-in Automated Approach for Well Modelling in Gas Fields
Authors: Baghdadi F. , Yin K. Yin , Madon B. 
Published: October 2017

Abstract
In oil & gas industry, it is evident that digitalization has become the leading technology to improve interactive data analysis in amultidisciplinary team. Exploitation of data has been a real challenge especially on mature fields with high real-time data frequency extraction on day to day basis. This paper aims to increasethe integration of data and workflow for building well models.
An automated workflow through programming has been implemented in offshore Sarawak, Malaysia involving three (3) main processes, which are:
procedures to use historical data to select IPR and VLP correlation for well models a workflow to predict well IPR using available surface data a built-in application to auto-match well models to selectthe most representative IPR model based onsufficient production data to be used in forecasting
The well performance and technical potential of the field was evaluated in accordance to this workflow, resulting in significant time-saving when analysing the massive pool of data. This enables the proliferation of real-time data usage promptly.
Employing this workflow minimizes misinterpretation of frequently ignored erroneous information compared to the conventional method. Greater reliability of well analysis using workflows helps to avoid perpetuating bias tendencies on data used for model calibration or quality check. This will result in better technical confidence needed to make decisions to move forward with development plans for a wide range of production rates and operating conditions. This paper will investigate the impact of using incorrect IPR or VLP versus the results of this workflow based on the same historical dataset. It will also demonstratehow the built-in automated process adds value in improving the understanding of well performance while ensuring that the models are calibrated to the entire historical data as accuratelyas possible.
Reservoir Mapping While Drilling Tool Overcomes Geological Uncertainties- Case Studies From Offshore Malaysia
Authors: Yen Philip Tan , Yen Kok Kwi , Hassan Nur Atiqah , Kyi Ko Ko 
Published: October 2017

Abstract
Reservoir Mapping While Drilling tool, consisting of a Deep Directional Electromagnetic Propagation Resistivity (DDEM) Logging While Drilling (LWD) tool and associated imaging software can detect bed boundaries and map reservoir bodies laterally beyond the wellbore being drilled. It has been successfully deployed to resolve and overcome geological and reservoir uncertainties when drilling wells offshore Malaysia. In Case Study-1, the DDEM tool was used to locate and navigate the drilling borehole assembly within a turbidite target reservoir successfully. In addition, the Reservoir Mapping While Drilling tool was able to detect and map a hydrocarbon bearing sand ten metres below the original borehole. In Case Study-2, the DDEM tool was used to identify the current Gas Water Contact (GWC) in a carbonate field which was experiencing high water cut early in the life of the field. In Case Study-3, the DDEM tool was used to determine the Top of Carbonate (TOC) in a carbonate gas field. It was critical that the top of carbonate be identified correctly, as the surface seismic data was relatively poor and was not able to pinpoint the TOC accurately. In the first case study, the hydrocarbon pay sand would have been completely missed if standard LWD tools alone were used to drill the well in a mature field. In the second case, the DDEM tool was able to locate and map the current Gas Water Contact (GWC), which was found 35 metres below the wellbore, in the carbonate gas field. It was found that the water was being produced through a karst zone, although all the previous production wells had been drilled horizontally way above the original GWC. In the third case, the DDEM tool was able to detect the Top of Carbonate, thereby allowing to set the casing shoe above the TOC. The plan was to set the intermediate casing shoe just a few metres above the TOC to avoid encountering severe mud losses when drilling through the carbonate reservoir. This paper will discuss the various steps involved in planning, designing and drilling of these wells using the DDEM tool with the associated reservoir mapping software. The methods used in imaging the reservoirs of interest and the bed boundaries and results obtained will also be discussed.
Development and Field Application of Proxy Models for Predicting the Shale Barrier Size using SAGD Production DATA
Authors: Kim Min , Shin Hyundon 
Published: October 2017

Abstract
There exists high uncertainty in modelling an interbedded shale barrier in heterogeneous oil sands reservoir, which causes a critical impact on SAGD performance. At present, despite the rise of research on shale barrier issues, few studies have attempted to address the prediction of shale barrier size except for 4D seismic data interpretation. In a shale interbedded oil sands reservoir, the SAGD production data such as the oil rate and steam-oil ratio (SOR) increase up to a peak point and decreases down to a trough point again, and the points are named inflection points (IP).
In this study, proxy models were developed for predicting the shale barrier size using reservoir parameters and the IP of SAGD production data. In addition, a field application was carried out for verification of the developed proxy models using the data from Suncor's Firebag SAGD project, Alberta, Canada.
The results of the screening analysis showed that the key parameters affecting IP of the SAGD production data were the reservoir thickness, horizontal permeability, vertical-horizontal permeability ratio, oil saturation, shale width (WD), shale length (LN), and vertical location of the shale (VL). The key parameters were selected and multiple simulation cases were generated using a latin hypercube sampling. As a result, the applicable proxy models for predicting WD, LN, and VL were developed by statistical analysis of the reservoir parameters, shale size and location, and IP. The statistical results of the proxy models show that the adjusted R-squared and predicted R-squared are high.
As a verification procedure, 3-D simulations were performed to reconstruct the predicted WD, LN, and VL, and the oil production profiles of the field well pairs were compared with the simulation results of the reconstructed shale barrier.
The oil production profiles show the similar trend between the simulation results of the reconstructed model and the field SAGD production data. Therefore, the developed proxy models can predict the shale barrier size properly, and may be useful for the field application.
Managing the Known and Unknown Risks - An Old Well Reabandonment Story
Authors: Mohd Mokhtar S. R. , Ardi A. B. , Wibisono R. , Zakaria M. , Shabudin A. 
Published: October 2017

Abstract
Located about 50 km from the nearest commercial city in East Malaysia, lies an old exploration gas well that was drilled and abandoned in 1952. This well, identified as well Orange 1, was observed to be leaking by a housing developer company in 2013 as they were progressively constructing houses in that area. This resulted in temporarily suspension of the construction works in fear of potential harmful gas leakage and explosion.
The well Orange 1 is a high pressure exploration gas well that was drilled to about 12,000 feet and immediately abandoned back in 1952. Given that this well was never opened to production, the reabandonment design had to be done based on the well still having the virgin reservoir pressure with the potential of flowing up to 7000 psi. This alone imposed several technical and operational challenges which requires lengthy and detail engineering approach. The reabandonment in many ways simulated drilling into a shallow gas zone. There was limited information available regarding the well and the original cement plugs were neither checked for depth nor tested during the original abandonment and their very existence was based on the number of sacks of cement reported to have been pumped in the drilling reports. It was theoretically possible to drill through the top 200feet cement plug and find full reservoir pressure at surface, so equipment and procedures had to be in place to accommodate the worst case scenario. Since this well was in the vicinity of a housing area, additional public risk and logistical challenges also had to be managed to ensure the deliverables are achieved in the safest manner.
This paper outlines the overall integrated project management process to evaluate all the down hole and surface risks, environment, public interest and logistical challenges and its related planning, solutions, risks management and lessons learnt from the 6 months execution phase. As this is the first land well reabandonment in Malaysia, it has now become a reference and benchmark for any near future land well reabandonment works. Together with the service sector, PETRONAS also carried out design and operation optimization process to even further enhance the execution.
Shallow Light Architecture: A Viable and Cost-Effective Solution for Marginal Reserves in Tunu Shallow Development
Authors: Handoko A. I. , Bimastianto P. , Maulana M. D. , Agriawan C. , Brahmantio R. A. , Abidiy I. , Setiawan T. 
Published: October 2017

Abstract
The current development of Tunu field level has reached a mature level. Finding target for new wells with adequate reserves to pass the economic cut-off limit has been a challenging task. In addition, with the recent low gas price environment, completing these marginal wells using currently proven Gravel Pack (GP) well design makes these wells uneconomical.
Answering the challenge, and with alignment to cost culture program, Total E&P Indonesie launched a collaborative project aiming for cost-effective wells against well reserves. Shallow Light Architecture (SLA) well design was introduced as the outcome of well architecture simplification process. For sand control, a successful period of trials of chemically-enhanced sand consolidation has boosted the confidence to implement sand consolidation on the industrialization phase as primary sand control in SLA wells.
This paper aims to describe a brief development of the technology, implementation, and results for the operator.
Driving Efficiency in Idle Wells Restoration through Risk Sharing Integrated Operations
Authors: Mohd Mokhtar S. R. , Wibisono R. , Zakaria M. , Shabudin A. 
Published: October 2017

Abstract
In the past few years, operators in Malaysia have intensified activities to restore idle wells. This was driven by the requirement to sustain existing production, high oil price and availability of resources. However, the success rate of each activity and efficiency of the operation was not encouraging as it was averaging at about 60%. This has become a huge concern to Malaysia Petroleum Management (MPM), the regulatory body of PETRONAS as 40% of investment spent to restore these idle wells did not yield the production gain that it was targeted. MPM sees this as value leakage that needs to be reduced significantly during current low oil price scenario.
A thorough analysis of the overall well intervention activities in Malaysia was carried out especially on the activities related to idle wells restoration. The focus was very specific to this area because idle wells percentage is as high as 50% from the total number of wells in Malaysia. This translates to a technical locked in potential of about 80,000 barrels of oil per day (BOPD). Most of the time, even though the planned cost of an activity is below the regulatory Unit Enhancement Cost (UEC) threshold to begin with, the actual cost surpasses the planned cost after the execution due to inefficiency and the small allowable error margin. With the low oil price scenario, coupled with low gain potential from idle wells, it was deemed necessary for MPM to put in a different strategy to manage this inefficiency and value leakages. After a series of engagement with the operators, root causes were established which includes inefficient resources utilization, poor technical solution, poor planning, weather limitation and lack of collaboration with industry key solution providers.
This paper outlines the process that MPM have implemented to provide the operators and service sectors a contractual platform at which all stake holders can share and formulate a win-win investment portfolio. The philosophy of the strategy is based on a risk sharing mechanism where operational efficiency and success rate of an activity are the main drivers to guide both the operators and service sectors. Specific Key Performance Indicators were defined to ensure the risk sharing mechanism is fair for stakeholders.
After the first implementation of this new strategy, MPM have seen the positive impact on the efficiency and success rate of both the operators and service sectors. Efficiency have raised to about 92% and success rate to about 85%. Efficiency which is defined as the percentage of work time of total time spent on the activity, played an important role in ensuring value leakage was reduced. This new mode of execution have now been further expanded to include production enhancement and well abandonment.
Fit for Purpose Behaviourism; a Design Culture
Authors: Siboro M. , Prabowo A. 
Published: October 2017

Abstract
Total E&P Indonesie (TEPI) is an integrated oil and gas company based in Mahakam Delta (Mahakam PSC), East Kalimantan. The fields are mature, with declining reserves found on existing & newly drilled well. Global situation dictates oil and gas industries (Including TEPI) to adapt by controlling cost (CAPEX & OPEX). Change Culture Compete on Cost and Deliver (4C&D) becomes the daily practice as it is considered as the means to survive. The change of culture & way of working has been integrated in the design methodology of the surface engineering team. The mindset is to implement "fit for purpose design", by utilizing existing material on stock and/or optimizing existing facility (instead of capital procurement). This approach is performed as such as design requirement is adapted to deliver the most favorable safe design. The methodology has been translated into several success stories; One of them is the revival of preserved gathering facility through minimalist concept. The project design execution embodied the "fit for purpose" design as the facility was revived with minimal effort (instead of complete reinstatement as per original design intent), with most material utilized from existing facility or existing stock. From process engineering and safety review, change of operating philosophy is foreseen when opting to the minimalist concept. However, with proper risk evaluation that was performed throughout the engineering phase, all possible risk has been identified, assessed & properly addressed. Furthermore, the change of operating philosophy has been assimilated seamlessly by the site operation team. The reactivation project has been completed smoothly on time (gas in before 1/4/2016), below budget (USD 1.3M realization / 1.5M budget) and maintained high safety standard as TEPI core value (no HSE incident). Currently, the facility has been put on stream, with recorded peak production of 16 MMscfd. This example had perfectly demonstrated that the change of mindset has been profound in delivering design that is suited for current economical environment. The willingness and the courage to get out from the comfort zone is one of vital element for success. The culture of opting to "fit for purpose" design as base case has been embedded in the DNA of TEPI surface engineering team, making it as one of the mandatory tools to survive.
Understanding Multi Zone Single Trip Gravel Pack Performance Improvement Process Using Technical Limit Methodology in Mahakam Delta
Authors: Wijaya R. , Muryanto B. , Wahyudhi F. , Styward B. , Sinaga H. A. , Masrur M. , Syafrudin M. , Kundoko B. , Daris M. F. , Nugroho H. M. , Ridhonmas A. 
Published: October 2017

Abstract
This paper presents analysis of Multi Zone Single Trip Gravel Pack (MZ-STGP) experience and performance in Total E&P Indonesie for more than decade in challenging field environment and global market condition. MZ-STGP has been utilized as a robust sand control completion methodology for sand prone reservoirs in Mahakam Delta since 2006. It enables saving of 3-6 days of rig time depending of well configuration compared to classic stack Gravel Pack (GP). More than 250 wells have been completed with satisfactory result and later drive the company business strategy.
Since the downturn of oil and gas industry in year 2014, a "cost efficiency project" called 4C&D (Change Culture, Compete on Costs & Deliver) was launched by Total to targets sustainable culture change and reduction in cost. It involves all aspect in company activities included in scope all operating, whether Total operated or operated by others. This project comprises a number of action plans – "roadmaps", where MZ-STGP became part of it. The target was to have an approach to identify current MZ-STGP performance and understand how to improve it by utilizing certain methodologies and tools.
The purpose of this paper is to provide the MZ-STGP practical steps implemented over the past few years using Technical Limit (TL) methodology. This methodology is expected to improve the efficiencies in whole aspects mainly related to performance monitoring as well as maintain low cost in order to have synergy with 4C&D spirit. The approach was influenced by comprehensive statistical data and ideas which resulting changes in the procedures as well as development in technology and equipment. As a result, a step change improvement in MZ-STGP completion performance was successfully achieved.
Right of Way Surveillance, Maintenance, and Higher Production Opportunities on Banyu Urip Export Pipeline
Authors: Amanu D. K , Kartika R. 
Published: October 2017

Abstract
The Banyu Urip Onshore/Offshore Crude Oil Export Pipeline is 20 inch carbon steel extending for +/- 96 km. As the pipeline is the key facility to transport Banyu Urip crude for export, the integrity management of the pipeline is vitally important. There are several aspects of the integrity management program; two will be focused on in this paper: Right of Way (ROW) maintenance and as-built capacity analysis to support potential varying production profiles.
Pipeline ROW maintenance is challenging due to several reasons: (1) the agreement made to give access to local communities who previously owned the land to enable farming, now creates access challenges for inspection and surveillance. (2) Managing ongoing local government and 3rd party infrastructure projects above the pipeline. (3) Geographical andweather conditions impacting accessibility. (4) Boat surveillance limitations on the offshore section of the pipeline. Proactive external engagements and new technology applications are considered key to a successful ROW maintenance program.
Proactive community engagements include effective socialization to local communities about the importance of pipeline integrity and the hazards asscoated with buried/submerged pressurized hyrdrocarbon pipelines. Additionally, establishing and maintaining strong government relations are also important to ensure potential infrastructure development around the pipeline ROW will not harm the pipeline or impede implementation of the pipeline integrity management program. Government alignment is also a key enbler for successful community engagement.
Utilization of new technology has enabled the operator to tackle some ROW accessibility challenges. The use of drones has resulted in patrol cost optimization compared with using helicopters.
Following pipeline construction and commissioning, various as built studies have been performed to test the pipeline across a range of production profiles and to determine if a higher operating envelope than original design basis could be established. These studies included detailed surge and stress analysis. Surge analysis was performed to calculate maximum pressure expected in pipeline; while stress analysis was performed to ensure pipeline integrity at higher production rates. The result shows the pressure in the pipeline could increase to 78 bar (26% increase), and flow rate increase to 374m3/hr (9% increase). Stress analysis confirmed that pipeline is capable of operating at a higher envelope (MAOP 83 bar at 78 degC, relieving capacity at 688 m3/hr – a 34% increase vs design basis).
This engineering assessment of the existing as-built facility can supporting Indonesia through enabling increased production without additional pipeline infrastructure cost.