bluuebunny/crossref_metadata_2025_split huggingface dataset:
Magnetic and Gravity Data Acquisition in Deepwater: a new Frontier for the Potential Field Geophysics
Authors: Gabbriellini Gianluca , Spadini Giacomo , De Marchi Eliana , Filippini Michele , Finotello Roberto , Indrigo Dennis 
Published: May 2016

ABSTRACT
The O&G industry is moving offshore into increasingly deep waters in order to explore for, develop and exploit hydrocarbon reservoirs in new frontier areas. Standard gravity and magneto-gradiometric acquisitions in such areas are usually performed with ship-borne and airborne techniques. This implies that, especially in ultra-deep waters, the measuring sensors are very far from the geological causative bodies, thus leading to a poor SNR.
Eni E&P is committed to adopting and deploying novel proprietary approaches and tools in these challenging environments. As part of an ultra-deep water E&P initiative, Eni and Tecnomare have designed, developed and tested the "AUVG", a new Autonomous Underwater Vehicle capable of carrying gravimetric and magnetometric instruments onboard for the acquisition of potential field data close to the sea bottom in ultra-deep water environments. The vehicle, which is carried by a supply vessel and launched from it near the area of interest, is autonomously capable of navigating underwater for up to 20 hours, reaching the sea bottom and starting the data acquisition, performing pre-programmed trajectories, avoiding unexpected obstacles, storing the entire data set and emerging in a predetermined position. The vehicle can be located using a radio, strobe lights and a satellite localizer. By means of a Wi-Fi data connection, it is also possible to download data and re-program a new geophysical survey.
Gravimetric and magnetometric data acquired by means of an AUV in deep water are characterized by a much higher SNR as well as a higher spatial resolution. These improvements have been experimentally highlighted by a recent test carried out in deep waters in the Ionian Sea.

INTRODUCTION
The measurement of gravity and magnetic field data, also generally named potential field data, is extensively used in exploration geophysics. The common goal of potential field methods is to improve the definition of subsurface geology. Gravity field data provide information about anomalous density within the Earth. The interpretation of the gravity anomaly and/or related quantities (such as its gradient) is useful to understand where the density contrasts are located. It is particularly useful in saline contexts, where the salt bottom is not always visible in seismic data. Magnetic field data are useful to highlight magnetization contrasts caused by basement uplifts and subsequently to identify oil and gas traps, if necessary.
Although it is not possible to determine a single source for an observed potential field anomaly, their interpretation can be useful in obtaining a geological screening of the area; they can provide constraints in the seismic interpretation phase and can also be used as input data for joint inversion applications. It should be noted that, compared to the seismic acquisition, the potential field acquisition is considerably less expensive.
Syngas Technologies
Authors: Al-Mulla Jassem 
Published: May 2016

Abstract
This paper will discuss the comparison between the three leading Syngas manufacturing technologies; Partial Oxidation (POX), Autothermal Reforming (ATR) and the Steam Methane Reformer (SMR) technology. Also, this paper will discuss the development of the Catalytic Partial Oxidation COPox syngas technology. The discussion will focus on illustrating the general syngas chemistry of each technology and where the COPox process fits into the spectrum of syngas technologies. It will also discuss the application of the first two technologies in commercial plants and some of the critical operating parameters that can influence the performance and the efficiency of syngas production such as, feed gas composition, operating temperate and pressure.
Syngas can use in the Fischer-Tropsch and methanol process, as fuel, or as an intermediate for chemical production. Syngas treatment and removal of sulfur, NH3, soot and HCN containing compounds is essential to the final application of the gas. This paper wills discuss the effect of the impurities in the syngas.
"What Happened To All My Gas?" P/z Plots In Layered Reservoirs
Authors: Ross Fraser 
Published: May 2016

Abstract
P/z plots for low permeability or layered reservoirs do not yield a straight line which extrapolates to the IGIP; they are curved and deviate strongly from the theoretical straight line. Consequently, the interpretation of the P/z plot is often grossly misleading and typically significantly underestimates the IGIP, leading to erroneous production forecasts and reserve estimates. The problem with the simple P/z material balance plot is that the pressure measured using a pressure build up test is not representative of the drainage volume of the well. When P/z plots cannot be analysed quantitatively, typically a numerical reservoir simulator is used to match the shut-in bottom-hole pressures and the continuously measured wellhead rates and pressures. However, a simple multi tank material balance method can provide valuable insights into the reservoir behavior and can be used either as a precursor to, or to replace numerical simulation. This paper describes a technique that can be used for medium to high permeability reservoirs.

Introduction
This paper discusses the problems associated with applying the simple P/z technique to layered reservoirs; plotting the downhole static pressure vs cum production will always give the wrong value of the IGIP. This paper presents how pressure transient data and PLT data can be combined with a simple multi tank model, which can be programmed in a spreadsheet, to provide a good understanding of the impact that reservoir layering has on the pressure behavior of the reservoir.
In order to provide pressure data for this analysis, a 2 layer, dry gas reservoir model was constructed using a reservoir simulator. The details of this model are shown in Appendix 2. Because a model was used to generate the data used in the interpretation, the model inputs of IGIP, kH, re, skin and non-Darcy coefficient are known so the results of the interpretation can be compared to the model inputs. In other words, are the calculated layer volumes consistent with the input values?
The pressures used for this presentation were obtained by shutting in the well (in the simulator) every year for a simulated 4 day pressure build up. The pressure transient data for the first pressure build-up were plotted using the conventional log-log plot and is shown on Figure 1.
Application of an Integrated Approach to Preserve Geologic and Seismic Consistency in a History Matching Workflow of a North Sea Chalk Reservoir
Authors: Sudan Hari , Tolstukhin Evgeny , Hu Lin 
Published: May 2016

Abstract
Reservoir surveillance using 4D seismic has become a valuable resource for managing decisions under uncertainty. This paper highlights an integrated workflow to preserve geological consistency while calibrating a reservoir model using 4D seismic and production data. We demonstrate a successful application of this approach on our North Sea chalk reservoir undergoing waterflood, where a number of repeat seismic surveys have been acquired over time and leveraged as a quantitative source of information for describing the spatial distribution of reservoir properties and compaction. This seismic monitoring data has resulted in the ability to better manage the waterflood by providing fluid movement insights and subsequent improvement of infill well placement. To capture geologic variability and ensure model predictability, geostatistical parameterization techniques using multiple-point statistics are used to represent the uncertainty in the reservoir model. Additionally, the workflow employs a rock physics model to generate a synthetic 4D seismic response from flow simulation. Inconsistencies between the predicted and observed 4D differences are used to classify the reservoir model shortcomings. The uncertain geological parameters are updated in an optimization loop through the minimization of a misfit function comprised of both production and 4D seismic misfit formulations. The closed-loop workflow is managed by an in-house computer-assisted history matching tool using a stochastic optimization algorithm. The integrated approach yields improved reservoir management by encouraging multi-disciplinary collaboration between geological, geomechanical, geophysical and reservoir engineering disciplines.

Introduction
The use of 4D seismic has proven to be a valuable resource for managing decisions under uncertainty. The task of reservoir history matching is generally an ill-posed problem because there exist as a number of potential parameter combinations that generate similar simulated reservoir pressure and production responses. The fundamental reason this occurs is history matching spatially distributes uncertain geological or dynamic parameters (e.g. porosity, permeability, etc.) using localized well information from production data. The geological parameters in between the wells remain largely uncertain or unknown. To reduce inter-well uncertainty, the spatially more dense 4D seismic data can be used to mitigate the non-uniqueness by reducing the number of acceptable models.
A fully integrated workflow has been developed to ensure the predictability in our model forecasts by preserving the geologic and seismic consistency. This workflow dynamically couples all elements of the seismic to simulation workflow by using a computer-assisted history matching procedure.
A Comprehensive Approach of Well Integrity Surveillance
Authors: Al Khamis Mohammed N , Al Khalewi Faisal T , Al Hanabi Mohammed , Al Yateem Karam , Al Qatari Ayman , Al Muailu Husain 
Published: May 2016

Abstract
The well integrity surveillance program is a mechanism applied to oil, gas and water production/injection wells to ensure the sound quality and healthiness of all their completion components. Currently, there are differences in the well integrity surveillance programs applied by field operators worldwide due to the differences in the causes of well integrity issues that are faced in every field or geographical location. Recognizing such differences, Saudi Aramco formed a Well Integrity Surveillance Guidelines and Best Practices (WISG&BP) team to review and establish a comprehensive well integrity surveillance program that can be applied corporate wide for all well types (oil, water and gas).
The developed program not only ensures the identification of well problems at its infancy but also maintains the healthiness and upkeep of Saudi Aramco asset. This surveillance program focuses on the following six primary well integrity surveys: Wellhead valves integrity inspection and greasing.Surface and Subsurface Safety Valves (SSV & SSSV) and Emergency Shut-Down (ESD) System functionality and integrity testing.Annuli survey.Landing base inspection.Temperature survey.Corrosion logging.
An application has been developed to streamline and automate the planning, scheduling, execution, data validation and data posting process to ensure compliance with these best practices. This application provides tracking capability of the surveillance program and initiates alert, notification and escalation to the responsible entity at every stage of the surveillance process. The wells with identified integrity issues are flagged on a Well Watch List and closely monitored until their issue is resolved. This surveillance program is reviewed and updated every 2 years to reflect the advancements in surveillance technologies and capture any necessary modifications based on arising field observations.
This paper summarizes the well integrity surveillance program applied in Saudi Aramco. It provides a workflow of the well surveillance process and describes the automation application used to capture and track the program implementation. The comprehensive strategy provided in this paper can be used as guidelines for maintaining the well integrity of all well types worldwide.
Treatment of Produced Water from Unconventional Resources by Membrane Distillation
Authors: Minier-Matar J. , Hussain A. , Janson A. , Adham S. 
Published: May 2016

Abstract
Unconventional resources (Shale gas/oil) use significant volumes of water for hydraulic fracturing (fracking). While some of the water used is fresh groundwater, there are more environmental pressures to use brackish water sources for fracking. This brackish water may need to be treated to lower the saturation levels and to allow mixing of field chemicals. Unconventional resources also produced high volume of flow-back water (produced water). This produced water (PW) contains high levels of total dissolved solids (TDS) and desalination may be needed to allow recycling or reuse of this water source.
Membrane Distillation (MD) is an innovative process that can desalinate highly saline waters (30,000–100,000 mg/L TDS) more effectively than reverse osmosis. As a proof of concept, bench-scale MD testing were performed on brackish and produced water samples (30,000 mg/L-60,000 mg/L TDS) obtained from Texas. Results have shown excellent TDS rejection (99.9 %) on all the water samples that were tested without impacting membrane's flux performance.
To evaluate the O&M and scale up issues, two one m3/day MD pilot units are currently operating side by side at a local desalination plant in Doha. Brine from the thermal desalination plant was used as representative high salinity water (70,000 mg/L), similar salinity levels could be found in brackish groundwater and/or flow-back water. It was assumed that all other contaminants that could cause membrane fouling (such as suspended oil, solids, organics, microorganisms) will be removed in a pretreatment step prior to MD.
Preliminary results showed that the pilot units were successful in completely removing salt. Flux was very stable for more than 2 weeks. However, it was concluded that pretreatment is critical for stable performance of the MD units. This presentation will provide up to date data on MD bench and pilot-scale performance with O&M issues and projected cost estimates.
Assessing Reservoir Fracture Potential over Kra Al-Maru, Riksah Structure in the Kuwait Gotnia Sub-basin
Authors: Srigiriraju Ramachandra , Heyam Heyam , Al Adwani Talal Fahad , Banik Nikhil , Chakrabarti Bhaskar , Ghneej Ali Abu , Alaa Moustafa , Amer Aimen , Jaradat Awni 
Published: May 2016

Abstract
We present an exploratory case study of the oil and gas field located onshore within the Gotnia sub-basin located in northwestern Kuwait (Fig-1). Main objectives of this study include: to delineate the Kra Al-Maru and Riksah structure, to establish fault network, to assess fractured reservoir in its entirety, to achieve optimal depth conversion, to identify and assess critical inputs for fracture modeling and to provide key inputs for geo-modeling, all which lead to describing the location.
Structurally, the area is characterized by four main fault systems. Most of them have subtle seismic signatures on vertical sections as observed on poststack 3D seismic data. The dominant trends in the region are oriented NS and NNE-SSW where the unique. Kra Al- Maru structure is oriented NW-SE, which delimits the main structural high; however, dominant structural trends observed in sets of wells show NS, NNE-SSW trends. The second fracture set observed in the wells is oriented NE-SW, marked by minor vertical throws. The third and fourth fracture sets are oriented WNW-ESE, NW-SE characterized by no fault throws. Observations from core studies also support results achieved in this study.
Riksah structure is a well-defined four-way-closure anticline and appears to be a reasonable areal entrapment of about 33 km2. Its prospectivity is dictated by fracture potential of the reservoir. It is separated by a saddle like feature from Kra Al-Maru structure located to the west of this culmination.
The study indicates that the actual orientation of the structure, has most likely undergone fault block reorientation, fault reactivation and relative movement and accentuated folding due to compression effect. The increased stress on the flanks of the structure and the local tectonics are responsible for rotation of structure, which contributed to the evolution of the Kra Al-Maru structure and the orthogonally oriented Riksah structure as indicated by our study. The structural analysis indicates that all major open fractures align NNE-SSW.
The Riksah structure is a well defined four-way-closure anticline; however, the prospectivity is dictated by fracture potential of the reservoir. The evaluation of the fracture potential of the reservoir is best served by the azimuthally (AVOAz) processed 3D seismic data integrated with well observations. However, in the absence of AVOAz data, the study is supported by integration of well observations and key seismic attributes. The seismic attributes are, edge detection/enhanced seismic attributes, combined with prestack seismic inversion attributes like the Poisson's ratio which is governed by established relationships at wells.
Pushing Maximum Reservoir Contact Applications to New Limits in Tight Facies: A Case Study of Middle East's Highest Reservoir Exposure Producer
Authors: Suwailem M. A. , Zarea M. A. , Saleh R. F. , Verma C. X. , Nooruddin H. A. 
Published: May 2016

Abstract
The paper presents the evolution of reservoir management strategies that supported a recently drilled penta-lateral producer, which set a company record of total reservoir contact in a major greenfield in the Middle East. This paper will investigate the maximum reservoir contact (MRC) evolution in the field, the design phase of this game-changing producer, lessons learned and future implications.
The reservoir management objective for this producer was to capture oil reserves in tight layers (less than 10 md) in a gas cap driven carbonate reservoir while delaying gas breakthrough. This design was employed to push the MRC application to new limits of more than 16 kilometers to deliver more production at reduced well requirements while honoring best-in-class reservoir management practices.
In the design phase, a very high resolution reservoir simulation model was used to model the performance of this producer. Several sensitivity cases were conducted testing various well designs in terms of lateral spacing and completion depths. Subsequently, this producer was drilled with smallest lateral spacing (62 meter) closer to the oil-water contact (OWC).
The drilling of five laterals in 6 1/8" slimhole was a challenging task that posed hole cleaning threats across the horizontal sections and risked tight hole turning to stuck pipe. Through careful planning and team collaboration between various departments, the well was completed successfully with minor problems. In addition, the well was completed with two permanent downhole monitoring system (PDHMS) gauges and inflow control valves (ICVs) to manage water/gas movement and to ensure lateral clean-up.

Introduction

Field Background:
The greenfield is located in the South Eastpart of the Arabian Penensuila and is primarily producing from one carbonate reservoir. The oil column in this reservoir is overlaid by a huge gas cap and is underlain by a weak aquifer. Gravity drainage mechanism with gas cap expansion is the main drive mechanism (Saleri et al. 2003).
Vertical and horizontal pressure depletion trends captured by AVA Geostatistical Inversion conditioned reservoir modeling: An example from Late Messinian lacustrine turbidities reservoirs, Nile Delta, Egypt.
Authors: Vaughan R.  D. , Ali M. , Mustafa A. , Adly T. , Sulistiono D. , Petrov A. 
Published: May 2016

Abstract
AVO and seismic inversion has been successfully applied during the exploration phase of the Late Messinian Abu Madi Formation in the central Nile Delta of Egypt. Several gas condensate discoveries were made using this technique as a Direct Hydrocarbon Indicator (DHI) and risk mitigation tool. Deterministic inversion was further employed to delineate the overall lateral extent of the field and gross reservoir character during the appraisal phase of one particular field. A comprehensive well data acquisition programme for several wells revealed a complex lateral and vertical reservoir stacking patterns with highly heterogeneous reservoir parameters. The reservoir sequence is attributed to lacustrine turbidities deposited in semi-isolated Late Messinian Basins. Informally, the Abu Madi Formation can be subdivided in to upper and lower members. Intraformational shale barriers and baffles are commonplace. The stacked reservoir sands cannot be visualised and differentiated by the existing deterministic inversion products but each sand package displays complex vertical and lateral pressure trends.
This paper describes an AVA Geostatistical Inversion process integrated with rock physics modelling (using differential effective medium theorem) of the wells to generate high resolution multiple rock property models with the aim of capturing reservoir heterogeneity and the observed pressure trends. The probabilistic representations of lithology, water saturation, permeability and effective porosity captured the range of uncertainty remaining after appraisal drilling to provide equi-plausible models to further de-risk future development of the field. Flow simulation modelling is used to monitor and predict pressure depletion trends to optimise further infill drilling and effectively manage the reservoir.

Introduction
The Late Messinian Abu Madi Formation is a prolific producing reservoir in the Nile Delta of Egypt. The first discoveries were made from the late 1960's onwards focused along the Abu Madi Valley trend (Rizk, 2002). A number of fields were subsequently discovered within this north-south trending incised valley trend. More recently exploration focused to the west of the Abu Madi Valley trend in the central Nile Delta area. Despite near-continuous exploration from the mid-1960's the area yielded no commercial discoveries. Following a phase of extensive 3D seismic acquisition and interpretation several fields were discovered from 2007 onwards. Most discoveries have made on structurally robust traps which usually comprises some stratigraphic trapping elements (facies changes and sand pinch-out). All discoveries were supported by positive AVO responses which generally conform to the mapped structural traps.