bluuebunny/crossref_metadata_2025_split huggingface dataset:
Reduce-Reuse-Recycle Approach in Managing Onshore Drilling Waste in North Senoro Drilling Gas Field Development Project
Authors: Ratri Widodo Andreas Krisbayu , Rahmadona Desmawati , Gunawan Hendra 
Published: October 2015

Abstract
Senoro, an onshore major gas-condensate field in East Indonesia, on the eastern arm of Sulawesi Island, is operated by JOB PERTAMINA – Medco E&P Tomori Sulawesi. Drilling campaign of 2013 – 2014 was carried out to drill 12 wells at four clusters which consist of 4 re-entry wells and 8 new development wells in North Senoro Gas Field.
By utilizing Water Base Mud as the drilling fluid for the overall well sections, the drilling operations generated two primary types of wastes – solid waste and liquid waste. Solid wastes consist of drilling cutting; used drilling fluid in its solid phase and contaminated packaging materials. Whereas liquid wastes consist of used organic chemical and the drilling waste water produced from fluid dewatering system.
Under the Governmental of Indonesia Regulation no.18 JO 85/1999 regarding Hazardous and Toxic Waste Management; drilling cutting and used drilling fluid were categorized as hazardous waste with code D220, the used organic chemical and contaminated packaging were categorized as hazardous also by the law definition, hence it required specific treatments in managing the drilling waste. Drilling waste water was required to be managed under the discharge limitation regulation of Act of Ministry of Environment no. 10/2010.
In this case study through a waste minimization concept, reduce-reuse-recycle approach is utilized to manage the produced drilling waste. Initiated by an engineering design that was taken thorough deep assessment to use to use water base and non-chloride content mud material, drilling waste management flow diagram is then developed and applied to manage waste related to the drilled well; general solid waste and general liquid waste.
By applying the selected drilling waste management flow diagram, the North Senoro drilling campaign can be performed within the waste minimization concept and all discharged parameters can be ensured within the regulation discharge limit.
Drilling Efficiency and Geological Restrictions in Carbonate Type Collector with MPD in Compare with Conventional Methods
Authors: Kulikov S. , Priymachenko D. , Bakhtin A. , Shilkin P. 
Published: October 2015

Abstract
Riphean anisotropic cavernous-fissured carbonate reservoirs of oilfield at East Siberia area – one of the most problematic objects of oil and gas production described in this article. Here is discussed geological substantiation and first result of new technology involving in drilling of Riphean carbonate reservoirs with "Controlled pressure technology" by recovery wells with horizontal bottom at the oil-gas condensate field in Evenki Region. Comparison results of conventional drilling and "MPD" (Managed Pressure Drilling) technology.
Riphean reservoirs drilling process could be provided in two options.
The first one – horizontal conventional drilling. As far as the bit penetrates into the reservoir we are seeing SPP (Stand Pipe Pressure) decrease which means we have total lost circulation. There was only one means for resolving this problem – using LCM (Lost Circulation Material). Due to complicated geology and high parameter of gas factor in Riphean reservoirs (losses while circulation/ gains while static), LCM was insufficient solution.
The second is to perform drilling process using MPD (Managed Pressure Drilling) technology. We have the advantage using lower mud weight compared with conventional drilling. MPD technology corresponds with geological conditions of Riphean reservoirs and can be more profitable in future production from these wells.
MPD technology with closed loop circulation system showed that we can "manage" BHP (Bottom Hole Pressure) and it really works in temperature conditions of 45 Celsius below zero in Evenki Region (East Siberia). In practice we have seen, that it was possible to achieve more gentle management of BHP than with conventional drilling using LCM. Also with "MPD" system in this oilfield we were able to drill the first ERD (Extended Reach Drilling) well. However, even with such extended horizontal section (1000 meters), a significant reduction of losses was achieved without using LCM. Total results of MPD technology we will see after DST (Drill Stem Test) of drilled wells.
New technology showed that it was a right choice to use close loop system and MPD. Also for drilling new wells in this Riphean carbonate reservoirs of this oilfield area we will use this experience. Best way to reduce catastrophic losses in abnormally low pressure reservoir conditions is reduce and control the ECD and details how to achieve it we have considered in this article.
The results: Reduced interval construction time. From 31 days to 24 days.Reduced fluid loss during drilling. From 2000 m3 to 1200 m3.Improved the operational safety by closing the loop and real time early kick and loss detection.
Cased Hole Ceramic Screen Cutting Completion Cost for Marginal Reservoir : Application in Tunu Field
Authors: Risatrio A. A. , Muryanto B. H. , Wijaya R. , Styward B. , Jackson R. , Gundemoni B. R. 
Published: October 2015

Abstract
Shallow gas development in Tunu field, East Kalimantan, Indonesia requires cost effective solution to safely produce multi layered sand prone reservoirs while maintaining low completion cost. Gravel pack solution has been deployed since 2006 and it enables producing small layers with multi zone single trip gravel pack system. However the system reaches its technical limits in term of cost, number of completed zones and well deviation. Developing alternative sand control solution is required to produce small marginal reservoirs and maximize recovery while maintaining robust sand control. Ceramic screen is considered as emerging alternative solution to cut sand control cost for marginal reservoirs. Ceramic material provides far superior erosion resistant compared to standard metallic screen. The paper will present the design of ceramic screen for cased hole Stand Alone Screen (SAS), its deployment in three Tunu wells and the production result from the completed reservoirs.
Full Field Integrated Modelling Throughout Life-Cycle Phases of Field Development : A Subsea Processing Case Study
Authors: Dianita Sandy , Gandi Rahmawan Setyadi 
Published: October 2015

Abstract
Traditional multiphase flow simulations often include less rigorous boundary condition assumptions, because flowline models are commonly isolated from both upstream well inflow and downstream processing facilities. Such an approach can be even more unrealistic if the flowline model network is complicated for example, where connected with subsea processing equipment. Within this kind of system, changes in fluid behavior are even more sensitive to overall operability. A full field integrated simulation, which includes well inflow, subsea equipment (XTs and manifolds), subsea processing, flowlines, and/or arriving facilities, offers a more realistic solution. This paper describes the application and value of performing full field integrated simulations throughout the life-cycle phases of field development.
The solver used for the simulation provides a powerful tool to screen design alternatives to identify the optimal field solution in a cost efficient way at an early design phase. In the detailed design phase the dynamic simulations using the same full field model can be performed to ensure system operability. Similarly, in the life-of-field operation phase, the same full field model can be used to perform real time metering and monitoring as well as "look-ahead" forecasting as part of an advisory system. This is usually instrumental for a challenging field production.
As the simulation model evolves since early design phase until the life-of-field operation, it promotes a comprehensive continuity. "One model one solution" provides an effective design and operation tool. Such a tool is able to provide a wide range of information that is relevant across multidisciplinary teams.
3D Petrophysical Modelling to Resolve Complex Reservoir Interpretation Problems: A Case Study from South East Asia
Authors: Aldred R. D. , Sritongthae W. 
Published: October 2015

Abstract
When using conventional petrophysical interpretation techniques on a clean sandstone reservoir in South-East Asia it was found that structure and heterogeneity in the formation caused the resistivity based Sw calculations to grossly underestimate hydrocarbons in place. The sands are layered and, although the porosity remains fairly constant, the permeability is highly variable with laminations of low-permeability water-bearing sands and high-permeability oil-bearing sands. The thickness of the layers is below the resolution of most log measurements.
This paper describes a technique for petrophysical interpretation of these reservoirs based on three-dimensional modelling of the formation properties. Extensive log and core data sets were available. Information from core was used to distinguish the different types of sand, NMR-T2 distributions were used to quantify the ratio of sand types at each depth and a saturation-height function was used to determine saturations for the different layers, based on height above the free water level. Synthetic log responses were created from the resulting models and inversion processing based on actual log responses was then applied.
Capillary pressure measurements showed that the low permeability sand layers had very high entry pressures, causing them to be water bearing through many intervals. The conventional resistivity logs were dominated by these thin water bearing layers, showing little effect of the presence of the oil in the high permeability layers. This is a similar effect to that commonly seen in laminated shaly sand reservoirs. UV fluorescence core photographs were found to be essential to the study as they clearly indicate the location of the oil and the oil water contacts in the cored intervals, even when the resistivity logs remain too low to differentiate the changes in fluids. This meant that the modelling could be verified in the cored intervals and then applied, based on the bi- and tri-modal T2 distributions, in the non-cored intervals. By modelling the formation properties at multiple scales, and taking formation anisotropy into account, the technique allowed good matches to actual log responses to be achieved and also provided good information for upscaling of the petrophysical properties to the reservoir model scale.
This case study illustrates a useful technique for situations where conventional deterministic and optimising routines don't give reliable results. It also provides a methodology, which can be built on in the future, to provide a more robust interpretation model for the many situations where formation structure and anisotropy affect log responses.
The High Temperature Effects on Pore Size Distribution of Tight Sandstone: An Application of Microwave Heating in Enhanced Gas Recovery (EGR)
Authors: Wang Hongcai , Rezaee Reza , Saeedi Ali 
Published: October 2015

Abstract
The present work studied the effects of microwave heating on sandstones with low porosity and permeability based on the comparison of pore size distribution (PSD) using Nuclear Magnetic Resonance (NMR) technique.
Microwave heating can heat the sandstone in a short time and cause physical and chemical change of rock and fluids inside. The heat evaporated water and changed the structure of minerals and pores so that the permeability increased which was measured from the Automated Permeameter. Before microwave heating, all samples are prepared into three different water saturations for NMR measurements: fully saturated using high pressured saturator, partially saturated using centrifuge and dry using conventional lab oven. Then the T2 distributions were measured in three different conditions. Samples were prepared and measured in the same way after heating.
It is found that Scanning Electron Magnetic (SEM), which can be used to compare the structure changes with high-resolution images, was used to support the NMR measurement; while Medical CT played a similar role by imaging full sample with lower resolution. Together they can give an interpretation of the T2 distribution or the pore size distribution.
The permeability increased after heating and the T2 distribution of each sample has changed. Minerals have been changed due to water evaporation and high temperature. It accounts for the change of T2 distribution. Comparing plots and images before and after heating, the heating effects are obviously positive to EGR.
We have had a good understanding of the effects of high temperature on permeability by studying the change of pore size distribution with NMR before and after heating. With the support of SEM and Medical CT, we got visualized evidence for our interpretation of the change of pore size distribution.
Kickoff Plug Best Practices for Shallow Wells in Awali Field, Bahrain
Authors: Hanna Rusty , AlGhani Sayed , Abreu Miguel De , Pohl Jonathan , Al-Hawaj Husain , Rosero Ivan 
Published: October 2015

Abstract
Setting cement plugs for sidetrack operations is a critical, challenging, and time-consuming operation. In many cases, a successful sidetrack operation requires several cement plug attempts or lengthy drilling operations, resulting in increased operation cost. In the past, when required to sidetrack a well, cement kickoff plugs were regularly tagged without having achieved the desired compressive strength, with added risk of stuck pipe in soft cement and increased wait-on-cement (WOC) time. The poor cement plugs usually resulted in a time drilling operation after additional WOC time. Placing a successful kickoff-plug (KOP) consistently on the first attempt is required for a cost-effective sidetrack operation, which, by itself, is considered an additional cost to any drilling project. In the Awali field in Bahrain, drilling operations faced the challenge of increased loss time in KOP operations. Operator wanted to reduce WOC time by improving the performance of the cement KOPs. The target was to complete the sidetrack operation in well depths less than 3,000 ft and static temperatures of about 140°F within 8 to 12 hr, after the cement plug has been placed.
A thorough analysis of previous design and execution cement practices was performed to identify the actions needed to optimize the previous performance of cement plugs. Advanced cement plug optimization software was used to support the evaluation of the risks associated with the placement of the slurry. Data from extensive laboratory testing of several cement slurry systems were used to evaluate the effect of the slurry properties on optimizing the system deemed most suitable for this application. The studies also included a detailed review of the industry best practices that are applicable to the conditions of the field. The results of the implemented best practices for the design and execution of KOPs in shallow wells in the field under study demonstrated an improvement of the success rate to 100% and better cement plug performance, contributing significantly to minimizing the time and cost of performing sidetrack operations.
Efficient Application of Large-Bore HEWD in Total Mud Loss Environment Saves Two Days Rig-Time, Offshore Mexico
Authors: Ayala Enrique , Banuet Siddhartha , Murillo Ricardo , Karrer Cesar , Arnaud Alex , Riquezes Cruz , Campos Nestor 
Published: October 2015

Abstract
In 2013 the operator initiated a horizontal drilling campaign to increase oil production in Sihil field, offshore Mexico. The new well plan required 14½×17½ and 12¼×14½ Hole Enlargement While Drilling (HEWD) in top hole sections. The challenges were different compared to other top hole applications in the area and include hard formation drilling with low density WBM in a total lost circulation environment (no surface returns). The BHA (bottom hole assembly) would be required to penetrate fractured limestone, shale and dolomite with UCS from 15,000 to 30,000 psi. During the planning phase, engineers realized that neither the 14½×17½ or 12¼×14 ½ HEWD sections had been attempted in a total loss situation in the region.
Solving the issues would require accurate BHA modeling and a unique hydraulics system that would effectively clean the hole, provide the necessary pressure drop required to efficiently dive the RSS (rotary steerable system), allow MWD demodulation and enable optimal hydraulic reamer operation. The drillstring would have to be dynamically stable for good directional control despite rollercone TCI pilot bit (IADC517) and 13mm PDC reamer cutters.
The first two wells drilled under these conditions experienced reamer nozzle erosion. To temporarily solve the problem three reamer nozzles were blank-out. While this did produce an immediate solution it forced rig personnel to activate the reamer at the surface leading to a dedicated trip for drilling out. Blanking out the nozzles also reduced reamer life by reducing lubrication on the cutter blocks.
Having evaluated root causes for all washout cases, a change to extended nozzles was proposed to reduce erosion on the retainer and the area adjacent the nozzle bore. Hardfacing material was added to the nozzle retainers to increase durability. The new nozzle configuration was modeled and compared to the old nozzle design. The results of CFD (computational fluid dynamics) analysis suggested the change would yield positive results.
The extended nozzle design was tested on Well-3X and Well-4X and reduced erosion on the nozzle retainer and adjacent area. Cutter block cleaning was improved while eliminating the dedicated drillout trip (48-hours rig-time). Hydraulics were properly adjusted to deliver the required pressure-drop to efficiently operate the RSS/reamer and obtain the optimum choke size for signal demodulation in total mud losses. The operating parameters outlined by the modeling system produced dynamically stable drilling while mitigating S&V during transition events and RPM/WOB.
Sustainable Zonal Isolation under Extreme High Temperature Conditions
Authors: Shadravan Arash , Shine Joe 
Published: October 2015

Abstract
Well integrity has an utmost importance for upstream operations that has resulted in many studies to improve zonal isolation. Few papers comprehensively investigated the elements involved in cementing service delivery that are conducive to both well integrity and zonal isolation for extreme high temperature conditions. Geothermal, High Temperature and High Pressure, Steam Assisted Gravity Drainage (SAGD), Cyclic Steam Stimulation (CSS) (also known as Steam Flood) and Fire Flooding are all examples where the cement sheath can experience extreme high temperatures.
This study emphasizes on sustainable zonal isolation throughout the life of wells facing extreme high temperatures. The purpose of this paper is to present the challenges of extreme high temperature cementing and show solutions used to assure cement integrity under such extreme environments. These challenges were reviewed and the most up to date solutions were discussed. The examples explained through this paper demonstrate the role of these critical elements for safe and environmentally friendly extreme high temperature well cementing. This analysis provides recommendations to sustain long-term zonal isolation when operations involve with extreme high temperature conditions.
Thinly Bedded Reservoir Study, Application of Sand-Slit-Clay (SSC)-SHARP-Thomas Stieber Juhasz Models, in a Deep Water Field, Offshore Sabah, Malaysia
Authors: Kantaatmadja Budi P. , Rashid Syamsina Bt. , Nurhono Achmad A. , Masoudi Rahim , Neville Tom , Taesoo Kim , Basu Debnath 
Published: October 2015

Abstract
Thinly bedded reservoir study in the deep-water area, offshore Sabah, Malaysia, was performed with the primary objective of improving the understanding of its complex geology. The nature of reservoirs, which are predominantly thin-bed and laminated sandstones of submarine fan environment, contain a high level of uncertainty in its lateral continuity.
Standard shaly-sand log analysis methods contribute pessimistic values of porosity and water saturation when applied to these reservoirs. Few techniques are then presented for the determination of these rock properties, which are more reliable with core and production data.
Core grain-size analysis of these reservoirs shows that clay content is generally low but the silt content can be significant. Furthermore, log responses show that porosity distribution and mineral-conductivity are influenced mainly by the silt-size particles.
A sand-silt-clay (SSC) model was then developed from density-neutron crossplot, which model is also used to determine porosity and water-saturation in addition to volumes of lithology components of the reservoirs.
Furthermore, other petrophysical technique, called SHARP, uses 1D convolution filters to match thin bed modelled log curves to their corresponding measured responses. A petrophysical evaluation using standard resolution logs and the thin bed resistivity (SRES) from image response are used to develop a thin bed model that yields high resolution logs.
For zones where the resistivity image indicates significant thin bed development, the standard petrophysical analysis should also indicate the existence of free fluid. Although the porosity tools cannot resolve the thin beds, they nevertheless represent the bulk volumetric over the interval, known as Thomas-Stieber-Juhasz (TSJ) method, and would be able to differentiate between porous zones with lower clay volume versus porous shales with high clay volumes. The main point is that if a thin bed interval has some calculated free fluid volume using standard resolution logs, then a thin bed analysis is warranted.
Early Assessment of Environmental and Social Risks and Impacts of a Shale Gas Development in Morocco
Authors: Barcelo Ignacio 
Published: October 2015

Abstract
An operator has been granted a reconnaissance permit for the Hauts Plateaux and the Boudenib Blocks in Morocco, and is exploring the feasibility of an eventual Shale Gas Development Project in these areas. Given the particularities of shale gas developments, and applying the principle of early identification of risks, a series of studies have been conducted for the early assessment of environmental and social risks and impacts that such a project could have.
Studies performed for identifying critical issues compromising the feasibility of the project were: Hydrogeological Studies, Environmental and Social Baseline Studies, Permitting Roadmap, and Conceptual Environmental, Social and Health Impact Assessment.
The Hauts Plateaux and Boudenib Blocks show a small population density and large uninhabited areas, they are amongst the poorest regions in Morocco. There is a general lack of surface water resources, but groundwater resources were found to have the potential to ensure the water supply for a shale gas development. The Blocks present sensitive areas, including a Biosphere Reserve and Ramsar sites. A typical shale gas development assumption was considered for identifying and preliminary assessing potential risks and impacts. The most critical issues identified included threats to existing fragile ecosystems, the potential impacts on groundwater resources quality and availability, the loss of livelihoods and potential need of resettlement of local communities, impacts on cultural traditions and community cohesion, or conflicts between the establishment of a new industry and the development priorities that are currently being considered by the relevant administrations for these areas.
The studies performed conclude that a Shale Gas Development in Morocco could potentially be feasible in terms of availability of resources, permitting, and potential impacts. The studies also identify a set of existing environmental and social constraints that would likely impact the development of the project, and that would have to be considered for managing the project's risks.