bluuebunny/crossref_metadata_2025_split huggingface dataset:
Effective Permeability 3D Model Unlock the Uncertainty Production in Low Perm Fluvial-deltaic Reservoirs, Nilam Field, Kutai Basin, Indonesia
Authors: Corbellini Jose Benito , Harnondo Ratno Adi , Negara I. Made Agus Sutha , Gultom Luhut Partumpuan , Hazman _ , Soenoro Amireno , Benyamin Benyamin 
Published: March 2015

Abstract
Nilam Field is located in Kutai Basin, East Kalimantan, Indonesia, which even more than 40 years of exploitation, these fluvial deltaic reservoirs, of age Early-Middle Miocene, still have significant reserves of gas, that occur in poor quality reservoir rocks in structural, stratigraphic or combination traps, that were not entirely examined. This case history describes some works carried out in this field over these low permeability reservoirs, locally known as G's sandstones, in order to understand the root of the erratic production results, evaluate the formation damage, identify the potential areas and present the right solution for recovering the undeveloped accumulations.
Seventeen cores were taken in these horizons, with the main purpose to obtain the necessary information for determination and characterization of rocks and the explanation of trapped phase. An understanding of multiphase properties as capillary pressure, water-gas relative permeability, fluid compatibility and the right model for effective permeability, calibrated by nodal analysis techniques, are mandatory to properly define the input for the 3D petrophysical models. In the past, the failure to fully understand these concepts, especially the effective permeability model and its relationship with the critical water saturation, less than 40% for these reservoirs, has led to a not clear understanding the controls on gas-field distribution. Therefore, effective permeability to gas as function of varying water saturation is the key factor to understand the reservoir productivity.
The integration of critical petrophysical aspects with geology using geostatistical methods had produced comprehensive overlay models that were used to delineate the best areas for developing the significant amounts of un-recovered reserves with minimum uncertainty in production. The use of this methodology has arrived not only to achieve this target but also has shown an incremental gas production as much as 10 times, in some areas of the field, during the last 2 years.
For this study, two sources of information were available: Core data and Log data. Both were analyzed to get reliable information to characterize the G Reservoirs.

Introduction
This history case, of erratic production forecast, describes some work carried out in a low perm fluvial-deltaic sandstones of age Early-Middle Miocene in Nilam Field.
Nilam Field that is located in Kutai Basin, east of Kalimantan, Indonesia, Fig. 1, was discovered in 1968, but after 43 years of production much of the reservoir remains to be understood.
These rocks, that exhibit normal reservoir quality but, in particular areas, poor gas production, were studied with the purpose to explain the disappointing gas rate results and assess the remaining considerable reserves, mainly in the eastern flank of the Nilam structure.
Utilizing GHV Management in Field Development Planning
Authors: Wiboonkij-arphakul Chaiyaporn , Tsai IngJye , Jablonowski Christopher J. 
Published: March 2015

Abstract
This paper discusses the challenges of integrating into an existing gas field a marginal field with poor gas quality that would otherwise be left stranded.
To prepare for the poor quality gas, this study added gross heating value (GHV) to the traditional scheduling analysis to ensure that the quality of sales gas blended from various fields would always meet specifications. The addition of GHV to the traditional scheduling analysis required devising a GHV forecasting method, creating a GHV management procedure, and implementing a new revenue allocation method. Each of these innovations required specific tasks. Examples of these tasks and their challenges are presented in this paper.
Evolution of Geosteering Technology Helped in Successive Development of a Brown Field - Case Study from Mumbai High
Authors: Anand S.K. , Kumbhar Jogeswar , Singh Uday , Jeelani Mohammad Sazid H.M. , Majumdar Chandan , Singh Juli 
Published: March 2015

Abstract
Mumbai High, a highly heterogeneous multi-layered carbonate sequence with shale intercalation, played a critical role to quench the energy thirst of a big developing country like India. Mumbai High field is divided into two blocks i.e., Mumbai High North (MHN) and Mumbai High South (MHS) by a major WNW-ESE trending graben containing impermeable shale. After 34 years of production, the field is in its brown stage and radical decline in production has been observed. Horizontal drain holes were introduced to counter this problem by increasing the reservoir exposure. However the biggest challenge faced so far is the placement of the horizontal drain hole within 2 - 4m thick layer with significant structural variations. Exit into shale due to presence of sub-seismic fault and minor dip change is a common observation while drilling.
Geosteering technique has developed as the industry has shifted its focus on horizontal well drilling. Initially wells were placed using log correlation, through understanding of the reservoir which often helped to drill a better horizontal well. The simple log-correlation technique was improved with the introduction of azimuthal measurements. However the approach was still reactive and a need was felt to have a proactive approach. Present sophistication has met the requirement by providing early indication of the approaching boundary.
This paper will illustrate various techniques for successful placement of drain holes in such complex reservoir. Also, it will capture the chronological evaluation of Geosteering technology and how they are used to develop this field. The drilled wells in all the cases have proven to be the successful drain holes and prolific producers compared to the surrounding wells.

Introduction
Mumbai Offshore Basin, a pericratonic rift basin in the western continental shelf of India, covers about 148,000 km2 from coast to 200 m isobaths and the sedimentary fill ranges from 1100–5000 m (Fig.-1). Several large oil and gas fields have been discovered in this Basin, and the presence of hydrocarbons has been established in the multiple pay zones belonging to L-III limestone reservoir of Miocene age in Mumbai high. The L-III limestone reservoir is a multi-layered reservoir and has been divided conventionally from top to bottom into major layers A, B, C, D, E, and F separated by intervening shale and argillaceous tight limestone. 'A' layer is further subdivided into Al, A2-I, A2-II, A2-III, A2-IV, A2-V, A2-VI and A2-VII and along with layers B, C constitutes the main producing horizon (Fig.-2).
Well Productivity Prediction for Laminated Reservoirs Using Borehole Electrical Image Logs.
Authors: Chokthanyawat Suchart , Daungkaew Saifon , Athichanagorn Suwat 
Published: March 2015

Abstract
Due to increasing costs in hydrocarbon exploration, formation evaluation needs to be efficient in order to avoid excessive expenditures. Proper reservoir characterization in thinly laminated reservoirs is a key to successful field development. These thinly laminated reservoirs are complex due to their vertical heterogeneity. As a result, there is low resistivity contrast between water and hydrocarbon bearing zones when standard resistivity logs are used. Thus, it is crucial to deploy a high resolution formation evaluation in order to capture reservoir pay and detect hydrocarbon zones.
This paper aims to demonstrate a methodology of using borehole electrical image log to determine effective permeability. The paper is the first attempt to develop a numerical technique to build a correlation between synthetic resistivity derived from borehole electrical image tool with other dynamic permeability measurements such as dual packer formation tester. A single well predictive model was used in the process to generate a high resolution numerical radial model from high resolution log data.
Since the 1980's, micro electrical imaging tools have mainly been used for sedimentological and structural interpretation, qualitative interpretation for sand quality, and also for the sand count. However, from the systematic integration of borehole electrical image, NMR, pressure transient from an Interval Pressure Transient Test (IPTT) in the thinly bedded reservoirs, it is possible to use electrical image log variations for permeability estimations. This study therefore aims to develop the methodology for actual field data to predict well productivity.

Introduction
Laminated formations pose two major evaluation challenges for reservoir engineers:-
1st is the classic low resistivity pay problem as seen in vertical wells. Layers of clay, silt and fine-grained sand distributed within a hydrocarbon bearing sand will significantly reduce the apparent resistivity measurement. This low resistivity results in wrong fluid identification and therefore this zone might be overlooked.
2nd is the high angle well evaluation problem. The same laminated formation, when measured by an induction tool at moderate - high relative dip, will exhibit an increase in apparent resistivity beyond that measured in the vertical well.
Again, the inaccurate calculation of water saturation and hydrocarbon volume may cause the error in reservoir estimation.
Geophysical Reservoir Characterization and Modeling of Marrat Carbonate Reservoir in Minagish Field, West Kuwait
Authors: Jalil Abdul Aziz , Verma Naveen Kumar , Al-Mutairi Khaled M. , Al-Khamees Waleed Khamis , Rahaman Mafizar , Laiq Kamran , Ahmed Mukarram , Sabry Ahmed 
Published: March 2015

Abstract
As a part of an integrated field development study, comprehensive seismic interpretation, velocity modeling and inversion were carried out for the Minagish Marrat reservoir. The geophysical lithology-porosity effects were imaged and quantified for the first time, and used for detailed reservoir characterization and 3D geological modeling.
Recently acquired 3D PSTM seismic data was used to interpret and refine the key horizons over the Minagish field. The multi-attribute analysis was used to quality control the horizon picking and to interpret the faults accurately, particularly since the data was contaminated with multiples. Advanced post-stack attribute analysis provided insights into the faults, fractures and matrix properties of the heterogeneous carbonate sequences to understand the reservoir architecture at all scales.
Several velocity modeling scenarios with combination of wells and seismic velocity were evaluated to investigate the structural uncertainty for accurate depth conversion. A total of 57 key wells were used to build a robust velocity model from surface to 13,000 ft with an average accuracy of + 10 ft at the reservoir level.
3D PSTM seismic volume was used for post-stack acoustic impedance inversion to map the reservoir properties from seismic. The objective of one of the key rock physics analysis was to understand the mineral-elastic response of the reservoir rocks. Advanced well log data conditioning with rigorous quality control was performed on 22 wells used in the inversion process. Fully integrated core and well log derived mineralogy results were used to prepare sonic-density scatter plots to understand and calibrate the response in terms of mineralogy (e.g. clay, dolomite, and calcite) as well as lithofacies with varying porosity. This meticulous calibration resulted in good relative and absolute acoustic impedance transforms to derive porosity, which in-turn was used for modeling the reservoir properties in 3D geological model. This model has provided a strong base for horizontal and multilateral well placement as the results from recently drilled first horizontal well has shown excellent match with the model predicted reservoir structure, lithofacies and porosity.
Recent Step-out Exploration in the Greater Sirikit East Area, Sirikit Oil field, Onshore Thailand, a Model for Overlooked Area
Authors: Saifuddin Farid , Phaungphuak Sunantha , Matha Sureena , Ratawessanun Watanapong , Nuada I. Nengah 
Published: March 2015

Abstract
Greater Sirikit East (GSE) Field represents recent step-out exploration success in the east of Sirikit Main Field. Sirikit Main was discovered in 1981 and remains the largest field in the basin, with surrounding smaller fields: Sirikit West (northwest, 1983), Thap Raet (north, 1988), Sirikit East (northeast, 1992) and Nong Jig (southwest, 1999).
GSE comprises of multiple blocks defined by structural and stratigraphic closures. It shares common reservoir and source rock with Sirikit Main. Some of the trap types and seals are also common. However, some trap types and seal elements are not typical in Sirikit Main. More detailed subsurface evaluations were conducted to explore all the working petroleum systems.
This is the key and challenge to the GSE that had been overlooked in the past due to the absence of considerable structural closure in the key horizon maps.
Aggressive step-out exploration in GSE started in 2006. More than 12 exploration/delineation wells have been drilled to date testing multiple blocks and plays. The exploration concepts have been continuously developed by taking the feedback from the well post drill evaluation. The new developed or refined concepts were then applied to the subsequent exploration/delineation drilling. This cycle allows better risk mitigation as well as more accurate well targeting.
To minimize exploration cost, time and risk, following strategies have been adopted whenever feasible: To use existing drilling surface location, to combine multiple targets and to provide back-up side-track target. Utilizing existing surface location made significant time and cost saving by avoiding costly land acquisition, access road building and time-consuming environmental impact assessment.
Continuous exploration and delineation drilling in 5 years has changed the GSE area. The previously overlooked large area that looks like a monocline in main marker maps turned out to hold multiple hydrocarbon accumulations involving both stratigraphic and structural traps.

Introduction
Greater Sirikit East Field is located just to the east of the Sirikit Field in the S1 concession, Phitsanulok Basin (Figure 1), Central Plain Onshore Thailand, approximately 400 kilometers north of Bangkok. The concession is 100% owned and operated by PTT Exploration and Production.
Sirikit Field was discovered in 1981 and remains the largest field in the basin. Up to 2000, 5 adjacent smaller fields have been discovered. Sirikit West Field in the northwest was discovered in 1983. Thap Raet Field in the north, discovered in 1988, Sirikit East in the Northeast, discovered in 1992, Nong Jig oil in the southwest, discovered in 1999, and Nong Pluang gas in the south-southwest, discovered in 2000. The first-discovered Sirikit Field is normally called as Sirikit Main Field in order to distinguish it from the neighboring fields bearing 'Sirikit' name.
Use of Nano-Metal Particles as Catalyst Under Electromagnetic Heating for Viscosity Reduction of Heavy Oil
Authors: Greff John , Babadagli Tayfun 
Published: March 2015

Abstract
In order for heavy oil and bitumen recovery to be efficient, all components present within the oil must be produced. To achieve a highly efficient production process is it essential that we are able to produce asphaltenic components and limit their precipitation. Solvent and conventional thermal techniques are largely limited in their ability to crack asphaltenic components. Thus, new technologies and catalysts are needed to be more efficiently recover heavy oil.
When nano-sized metal particles are present, they catalyze the breaking of carbon-sulfur bonds with in asphaltenic components. The result of this process is an increase in saturates and aromatics, while simultaneously reducing the aphaltene content. This process dramatically lowers the viscosity of heavy oil and bitumen by significantly reducing the average molecular weight. This effect can be dramatically increased by having a strong hydrogen donor present, and can be completely inhibited by the removal of all hydrogen donors. When conducting these types of reactions in-situ, it is very difficult and expensive to introduce strong hydrogen donors. Therefore, it is imperative that hydrogen donors be created within the oil rather than be introduced from an external source.
In this paper, we investigated the effects of microwave radiation, using a s 2.45 GHz emitter, on the recovery of heavy oil from a sand pack. Experiments were conducted with and without nano-sized nickle catalyst being present. Heavy oil samples were heated at different power levels until recovery of heavy oil leveled out. In all cases, the nano-nickle catalysts performed better than their microwave oil counterparts. This is due to the increased cracking and vaporization which was demonstrated by Greff and Babadagli (2011) to take place in the presence of nano-size metal catalyst and microwaves.
4D Seismic Integration with Production Analysis for Pressure-Saturation Detection
Authors: Mad Sahad Salbiah , Basaharudin Shuhadah , Abdul Halim Mohd Firdaus 
Published: March 2015

Abstract:

Introduction
4D seismic (or seismic reservoir monitoring) have been applied to many fields in the world, to monitor reservoir changes due to production. Monitoring reservoirs based on changes on seismic response due to fluid substitution and/or changes of pressure are able to locate bypassed oil, water/gas-flood fronts or steam-fronts.

Objectives and Methodology
The primary objectives of this study are integrating the 4D production data with seismic difference maps and determine the changes occurred in the reservoir because of hydrocarbon production or by the injection of water/ gas into the reservoir by comparing the repeated production datasets. Suitable methodology using PETRONAS In-House software were developed to search for the best results in three individual analysis; (i) interpretation using Production History (all region), (ii) integration of tracer database with seismic attribute maps (south west region) and (iii) integration of Saturation Data with 4D Quadrature Amplitude Difference Map (all region).

Geological Background
The reservoir in Z field represents mid-slope turbidites consisting series of fining upwards sequences, contain basal conglomerates and channel sands associated with levee and overbank sediments. The oil and gas in the field trapped in Early to Mid-Miocene reservoir sands above a faulted dome caused by underlying salt intrusion. The reservoir sub-divided into two mainpackages based on Calcareous Nanoplankton (CN) age dating.
Effect of Heat Treatment on Mechanical Properties of Expansion Cone Material
Authors: Qamar Zahid Sayyad , Pervez Tasneem 
Published: March 2015

Abstract
AISI D6 is a high-carbon high-chromium cold-work tool steel. It has excellent resistance to wear and abrasion, high compressive strength, and good edge holding quality and dimensional stability. These properties make it an ideal choice for use as a tool for blanking, punching, cropping, shearing, trimming and clipping. One of its most promising and important applications is in the form of conical mandrel for expansion of steel tubulars used in oil and gas exploration. Solid Expandable Tubular (SET) technology is being successfully employed for various downhole applications such as slimming of oil and gas wells, and isolation of water-producing zones. The mandrel, made from a special material (generally D6 steel), is hydraulically pushed (or mechanically pulled) through a steel tubular. This cold work expands the tubular beyond its elastic region, causing permanent deformation. To withstand the high level of repeated thermo-mechanical stresses, cone material must have certain specific properties. The work reported in this paper covers heat treatment and mechanical testing of tensile and impact specimens of D6 tool steel. The heat treatment process consists of annealing, hardening/austenitizing, air or oil quenching, and single or double tempering. Mechanical testing includes hardness, tensile properties (elastic modulus, yield strength, ultimate strength, and ductility), and impact strength. Analysis of the test results leads to the identification of an optimal heat treatment sequence for D6 steel that would yield the best combination of desired properties for the expansion mandrel. Optimum material properties would ensure dimensional accuracy of the expanded tubulars and a longer mandrel life.
Use of Reservoir Simulation to Help Gas Shale Reserves Estimation
Authors: Segatto Michele , Colombo Ivan 
Published: March 2015

Abstract
Scope of this paper it to supply a workflow for gas shale simulation: starting from selection of best porosity model, through a definition of the most impacting phenomena hierarchy, it comes to a real application on gas shale in Barnett basin.
Gas shale exploitation consists mainly in massive drilling campaign: this strategy can be successfully implemented where the costs per well is low, but elsewhere an accurate investigation including numerical modeling of gas shale reservoirs could be essential especially for defining optimal well spacing.
We test several implementations of multi-porosity models (dual porosity, multi porosity, dual permeability). Even if all the models can simulate properly gas shale production we use "single porosity-like" that couples the advantage of dual permeability and single porosity models.
Tests on synthetic cases have shown that gas production from shales is meanly affected by fracture spacing, proppant distribution inside induced and natural fractures, desorbed gas and in situ stress change.
A real case of shale gas exploitation in Barnett shale is successfully matched by single porosity-like model, with SRV extension from microseismic mapping, 'water saturated' and pressurized hydraulic fracture, adsorption and change of in situ stress. Match of the water flow-back is obtained with non-equilibrium initialization: setting fracture cells with higher pressure and water saturation than surrounding ones. The matched case is then used as starting point for further analyses and sensitivities.
Final goal is to provide a workflow for frontier basin where few production data are available with respect to what happens in USA and to calibrate decline curve for reserve estimation.

Introduction
Referring to gas shale means in 90% of cases talking about Barnett Basin (Texas, USA). They symbolize the ideal play with huge number of wells already producing and where the market condition gives the opportunity to massively apply available technology and to test new development strategies. Anyway uncertainties still remains. Decline curves analysis are largely used to assess reserves and future development plans, but reservoir simulation can give an added value adding more physics or controls compared to Decline Curves.
As known, 3D simulation of gas shales is not a simple task because of complexity of storage and transport system, long water flow-back period, uncertain proppant distribution, gas desorption, etc..