bluuebunny/crossref_metadata_2025_split huggingface dataset:
Multilateral Drilling Under Challenging Conditions
Authors: Hariri Nour , Al Subhi Isehaq , Al Sharafi Mohamed , Nasrumminallah Nasr , Al Balushi Said 
Published: November 2012

Abstract
Since early 2010, one of the producing oilfields located in North of Sultanate of Oman required drilling optimization to sustain the development of the field and triple its production. The objective was to drill infill wells to maximize the reservoirs’ ultimate recovery. A secondary objective was to replace some of the mechanically completion-failed multilaterals with new horizontals. A six-well campaign was launched aiming to improve the well delivery and reduce the authority for expenditure (AFE) costs. The campaign targeted the drillability of the wells with major collision risks, hole cleaning and casing running in unstable shale formations, and well placement in a 2 m thickness reservoir eliminating unnecessary sidetracks.
High-Resolution LWD Resistivity Images for Carbonate Facies Identification and Geosteering
Authors: Mahiout Said 
Published: November 2012

Abstract
Accurate placement of the borehole within the reservoir and identification of features impacting producibility are key elements for success. Experience to date, shows that the drilling environment offers a good platform for high definition electrical borehole imaging. At the time of drilling, invasion and borehole wall rugosity are often minimal and electrical images generated by sensors that rotate with the drill string provide a full coverage of the borehole. It also provides an opportunity for real-time geological analysis while drilling and the decision making that is unavailable with wireline. Detailed analysis of images reveal discrete sedimentological and textural features aiding facies recognition in carbonate reservoirs. These facies can be up-scaled to facies associations and eventually used for depositional environment interpretation. This leads to wider prospect delineation and confirmation of the local geological model. The study also demonstrates the strength of early geological information in high-resolution for reducing geological uncertainty at an early development drilling program.
We show case studies from several carbonate reservoirs in which high resolution electrical images have been acquired in conjunction with reservoir navigation (well placement). From post well analysis, we can define the key criteria that help in recognition of reservoir position; correlatable sedimentary surfaces and image facies/patterns. We test the distribution of facies and sedimentological features that can be recognised in horizontal boreholes by comparison to vertical offset wells, in addition to automated facies recognition from image log responses. The development of a Sedimentary or carbonate facies steering technique using high-resolution images with a predictive and real-time interface will reduce uncertainties related to and better aid geosteering within the desired "sweet-spot" of a variety of clastic and carbonate reservoirs.
Pore Pressure Prediction Challenges in the Middle East Region
Authors: Khazanehdari Jalal 
Published: November 2012

Abstract
In many hydrocarbons-prone provinces of the world (the North Sea, Gulf of Mexico, West Africa, Caspian and other areas) abnormal pore pressures have now been widely observed. Accurate assessment and prediction of pore pressure and fracture gradient formed an essential part of the planning process particularly for exploration and deep drilling where no or limited pressure data are available.
Although the fundamental objective for pore pressure imaging is to provide pressure data ahead of drilling, the pore pressure analysis should be carried out at different stages of the drilling: (i) Pre-drill (using seismic and rock models), (ii) while drilling (act as support and update using real-time data) and finally (iii) post-drill (support role and improve pressure evaluation of an area).
An estimation of pore pressure can be obtained from seismic velocities where disequilibrium compaction is the dominant pore pressure mechanism during all the three mentioned stages (pre-drill, while drilling and post-drill) by using a velocity-to-pore pressure transform. However, the borehole or/and surface seismic velocities must be the true estimation of the interval velocity of rocks as well as of adequate resolution particularly for well planning purposes. In case of presences of other pore pressure mechanism such as hydrocarbon generation, Osmosis, etc, the industry still does not have a established method(s) for pore pressure prediction and often such mechanism are ignored due to their complex nature and lack of predicative methods.
Here, after reviewing the pore pressure challenges and mechanisms in the Middle East, we discuss the importance of the key pore pressure mechanisms such as; disequilibrium compaction, fluid migration, hydrocarbon generation.
Interpreting CO2 Pilot Floods in Heterogeneous Carbonate Reservoirs
Authors: Al-Hammadi K. , Al-Yafei A. , Rawahi A. , Hafez H. H. , Ghori S. G. , Putney K. L. , Matthews T. R. , Stadler M. P. 
Published: November 2012

Abstract
A poorly designed and executed pilot may lead to incorrectly rejecting an appropriate EOR process or conversely implementing an unsuitable EOR process. This paper illustrates a systematic approach to selecting a suitable design concept for a miscible CO2 injection pilot for a large onshore oil reservoir in Abu Dhabi, UAE.
Selection of the design concept was based on evaluation criteria determined by the objectives of the pilot. The process incorporated pilot-specific and field-development-level considerations into the development of evaluation criteria, which were subsequently used to assess multiple pilot concept alternatives. An extensive simulation study evaluated dozens of potential well options, focusing specifically on the impact of multiple well types and orientations of wells (production and injection) on oil recovery. The process resulted in a pilot concept that is optimal in terms of net present oil recovery and minimization of CO2 migration that could result in misinterpretation of pilot results.
Protecting the Digital Oil Field from Emerging Cyber Threats
Authors: AL-Issa Ayman 
Published: November 2012

Abstract
Whilst best-in-class automation has been put place in industrial plants during the past few years, brought about by the developments in Industrial Control Systems (ICS), the industry has become vulnerable to new types of industrial risks. The Distributed Control Systems (DCS), Safety Instrumented Systems (SIS), Fire and Gas Systems (F&G), SCADA Systems, etc that were put in place are essentially computer systems and became the source of concern as these have become intentional targets to hackers, espionage and blackmailers. The cyber security threat to process control networks and systems was also increasing with successful industrial attacks taking place.
Integrated operations in exploration, drilling, processing, refining and almost all oil and gas process operations are using such systems. The Digital Oil Field (DOF) vision materialized as a result of the advances in the application of automation, remote control, real-time data acquisition, and the enablement of collaborative work environments. This vision essentially raised the need to integrate the process control systems with corporate business networks. This has led to the vital need to put in place a robust industrial cyber security infrastructure. This paper will discuss:
A first of its kind cyber defense infrastructure design for protecting the Digital Oil Fields and Critical Infrastructures from Cyber attacks. The importance of developing the integrated systems design concepts incorporating at its core the ICS Security by design. The value of engaging digital security specialists at the Front End Engineering Development (FEED) stage in Digital Oil Field projects.
Process Management Strategies for Performance Improvement of Intelligent Field Commissioning: South Ghawar Case Study
Authors: Ruvalcaba Velarde S. A. , Oubiña A. 
Published: November 2012

Abstract
The Intelligent Field in Saudi Aramco is gaining widespread applicability after successful implementation in its oil fields for real-time data acquisition. The historical field data collected on equipment status and project development enables to build a case study on process management strategies to improve the performance of Intelligent Fields surface facilities project execution and deployment.
The application of this study focuses on the analysis of the project commissioning stage of Intelligent Fields surface facilities and how business strategies can increase the efficiency of the process through the involved organizations. Project commissioning requires an integrative process and operational effort across internal organizations: facilities, projects, production and operations, as well as the involvement of external organizations such as equipment manufacturers, contractors and service providers.
The results present an integrative approach on process workflow optimization and performance measurement for project execution as well as gap analysis and root cause analysis for continuous improvement. Here, the asset team involvement is recognized as a central entity that brings together stakeholders to pursue improvement and measure implementation through strategic alignment with business goals.
The case study contribution resides in how to foster efficiency in the project execution of Intelligent Fields surface facilities through performance improvement strategies. Efficiency is driven by cross-organizational teams who mitigate the challenges throughout the commissioning and start-up stages.
Improving Sub Salt Wellbore Stability Predictions Using 3D Geomechanical Simulations
Authors: van der Zee Wouter , Taylor Jack , Brudy Martin 
Published: November 2012

Abstract
Some of the most active and high profile hydrocarbon plays currently being explored and developed around the world lie below a salt canopy. Drilling through a thick salt canopy has the potential to provide a faster route to reach a sub-salt objective rather than drilling through the overpressured sedimentary section in a supra-salt mini-basin. Unfortunately, numerous geological factors can complicate the drilling leading to expensive sidetracking or casing operations. Wellbore stability problems, such as unexpected low fracture gradient, are relatively common while drilling close and out of salt structures. Significant savings on drilling costs can be made if potential wellbore stability problems could be identified and avoided in the well planning process. In this paper we present a workflow to improve wellbore stability predictions for drilling through and near salt structures.
Common assumptions in wellbore stability studies on stress magnitude and orientation are not valid while drilling close to a salt body as salt structures create, due to their shape and rheological behavior, a perturbation of the stress field with strong spatial variation of the principal stress magnitudes and orientations. To provide realistic stress input data for wellbore stability predictions, the stress fields around salt structures are simulated using non-linear materials and realistic 3D geometries. The workflow presented in this paper provides an efficient way to create realistic 3D finite-element based geomechanical simulations from these complicated structural data.
The workflow allows for a detailed simulation of the stress field around salt bodies that is new to the hydrocarbon industry and helps to significantly reduce the risk for wellbore failures of increasingly costly wells drilled to exploit, e.g., sub-salt plays in the Gulf of Mexico and offshore Brazil.
Optimize Early Oil Production Facilities for a H2S Environment
Authors: Scharner Manfred 
Published: November 2012

Abstract
Optimize early oil production facilities for a H2S environment
Companies active in Exploration & Prodution (E&P) are entering blocks with the target to explore and find new Hydorcarbons (HCs).
Probably most of those E&P companies are chasing "early roduction", once they have discovery promising a feasible commercial discovery. Moreover, this early productionshould be done in an optimized way. This paper outlines the approach that OMV has taken in order to "optimize the early oil production in an H2S environment" for a block in Kurdistan, Region of Iraq.
Looking at the project environment, the first question we needed to answer ourselves was: Optimized in which respect?
Highest safety / HSSE standards? High H2S (&gt; 10% in the associated gas) content encountered in the DST! Shortest time for oil to produce, deliver and commercialize? Earliest possible production with standard equipment from the shelf Maximize initial oil production? Just produce to the limit with no proper knowledge (no appraisal done yet) of the reservoir and the reservoir drive.
The answer to the above questions was not an easy one, however, with HSSE being OMV's priority in all operations "SAFETY First!" has been clear from the very beginning. Independent from all other technical and business issues, OMV started a "Pre development Study" with the target to have a plan forward, if we would encounteroil in commercial quantities. Actually, that study was started prior (!) to the spud of the first Exploration well.
this created certain costs, but the study provided valuable input for the definition of our "optimized" solution under the given project environment.
The following steps in the project definition and developmentwill be introduced in detail at the SPE conference:
Conduct Pre-Development Study: Identify country specific basics Opportunity Framing with definition of scenarios "Do we look wide enough?" Define the "optimized - preferred scenario" Minimum economic field size: Prove the Scenario (OPEX+CAPEX) against the MEF Prepare contracting / procurement strategy Prepare and float the invitation to tender for the early production facilities
Can Simulation Models Validated with Waterflooding Data Reliably Predict Three Phase Flow Processes of Gas and WAG Flooding?
Authors: Al Harbi Amal , Ghedan Shawket G. , Brantferger Kenneth , Kompanik Gary Steven 
Published: November 2012

Abstract
Several giant carbonate reservoirs have undergone decades of waterflooding, and are now transitioning to EOR recovery processes. Simulation models that were calibrated via history matching while undergoing a waterflood (i.e.two phase flow performance) are utilized now to predict three phase flow performance encountered with EOR processes. How reliable are these predictions? Are they accurate enough to be used for business decisions?
In this work, validity and reliability of simulation models, that has been history matched by two-phase flow processes of water flooding, to predict the performance of three-phase flow of WAG processes was assessed.
To accomplish study objective, fine grid of two 5-spot sectors model was built and then upscaled. Upscaled model was then history matched to the results obtained from the fine model using water flooding data and utilizing pseudo functions data. The resulted cases as well as the fine model were then taken to prediction to estimate the performance of three-phase flow of gas and WAG processes. Results of fine and coarse models were then analyzed and compared to draw conclusions on the reliability of the coarse models to match the predicted results of the reference model of the fine simulation model.
Simulation Modeling for Optimized LWD Fluid Sampling Under Different Invasion Profiles
Authors: Agrawal Samarth , Coskun Sefer B. , Hunnur Anup 
Published: November 2012

Abstract
Understanding the properties of formation fluid is a critical step in reservoir characterization. The use of Logging While Drilling (LWD) based fluid sampling becomes increasingly important in high risk scenarios. The LWD environment is significantly different from that of Wireline (WL) for sampling operations as the dynamic filtrate invasion is still in effect. LWD sampling is a relatively new technology and its sampling efficiency compared to WL sampling is not well known. This study aims to understand the effects of dynamic invasion processes on LWD fluid sampling and compare its performance with WL based fluid sampling. The results of the simulation study performed revealed that when the wait time after the drilling is optimized, LWD can provide cleaner samples in shorter cleanup time than WL sampling. It also revealed that the reservoir fluid breakthrough time would be shorter in LWD sampling compared to that of WL. This study indicates that with proper modeling, an optimized sampling program can be executed to meet the objectives of the LWD sampling operations in the most economic manner.
Rig less Innovative Practice to Restore In-Active Well Productivity Off Shore Field Abu Dhabi.
Authors: Ladmia Abdelhak , Al-Marri Faisal M. , Hassane Mohamed Abdelsalam , Al-Neaimi Ahmed Khalifa , Khalil Hassan Ibrahim , Ibrahim Mohamed El-Sayed , Santhanam Kalakad , Abu Chaker Hicham , Al-Sheikh Hosny Mustafa , Moslem Samaawi , Al Marasy Hatem , Salsman Alan 
Published: November 2012

Abstract
Several wells in Offshore field Abu Dhabi are unable to flow due to Low Well Head Flowing Pressure LWHFP and also other wells are unable to flow due to Asphaltenes deposit causing a restriction under certain conditions of pressure and temperature even after a remedial job using a mixture of Xylene-Diesel (20% / 80%). However the well in this case, Well-1, has a combined problem being unable to flow with both LWHFP & asphaltenes deposit.
In some applications the field layout and operation conditions also cause restrictions in production from the producing wells. The use of the technique of re-perforation using a 2’’ Premium Deep Penetrating Gun plus additional acid stimulation with a coiled tubing unit CTU to remove formation damage through double casing is a cost effective way to lower the skin and boost the flowing pressure of LWHFP wells.
Remediation of LWHFP often requires a complex and time consuming intervention (Acid Fracturation, Side Track etc.) with relatively low success rate, which is perhaps why thousands of wells globally currently exhibit LWHFP and cannot be produced due to high line pressure (HPP) in the gathering pipelines.
The objective of this paper is to highlight the challenging yet successful techniques implemented to remediate restricted tubing due to asphaltenes precipitation and restore productivity in the off-shore Field, Abu Dhabi. These jobs are done rigless to aid efficiency and keep cost down and have been successful at getting the wells back on line.
Value of Well Test in the Determination and Characterization of Natural Fractured Reservoir Properties in Large Onshore Abu Dhabi Carbonate Field
Authors: Abdul Rehman Abdul Samad , Kumar Arun , Bejaoui Riadh , Nazarbayev Nurbek , Shuaib Mohamed , Sirat Manhal , Singh Maniesh , Al-Dayyani Taha , Ancuta Cristian , Farcasanu Angelo , Gholipour Ali , Belayneh Mandefro 
Published: November 2012

Abstract
Identifying natural fractures and assessing their impact on flow behavior in hydrocarbon reservoirs have been one of the key challenges in defining the field development strategy. Failure to correctly represent the natural fractures when working on a reservoir development plan can lead to poor performance and failure to analyze reservoir response. Pressure transient testing is widely recognized as a core competency in the oil industry as it provides subsurface specialists with valuable information regarding the reservoir properties, well connectivity to the reservoir and extent of reach into the reservoir.
When borehole image (BHI) data triggers a signal that fractures are seen in wells but flow rates do not show production dominated by fractures, the engineers working on the reservoir need to pay attention to pressure transient tests. Depending on the contrast between fracture permeability and matrix permeability, pressure transient analysis in a fractured reservoir can show clear dual porosity behavior, or the effect can be masked by the wellbore storage. The latter happens when the contrast between the matrix permeability and the fracture permeability is small.
The two parameters which characterize a dual porosity model are the storativity ratio, ω, and the inter-porosity flow coefficient, λ. The average value of λ for the vertical wells studied is 25*10−4, confirming a low contrast between fissure and matrix permeability. For the storativity ratio, a typical value is between 0.001% and 0.1%. An average of 0.03% has been calculated from the well tests.
With the results from pressure transient tests, BHI and core description, fractures have been defined as mild with relative low-intensity. Numerical modeling on a field sector was employed to test the impact of the fractures on production.
Hydrocarbon Habitat of the Early Permian Unayzah Formation in Abu Dhabi
Authors: Taher Ahmed , Al Shateri Abdulla , Al Mehsin Khalil , Witte Johan , Al Zaabi Mohammed 
Published: November 2012

Abstract
The pre-Khuff principal hydrocarbon reservoir, Unayzah Formation, consists mainly of distal braid plain sandstones characterized by aeolian and sabkha facies with minor fluvial units. It extends between the pre-Khuff and the Hercynian unconformities. In Abu Dhabi, the Unayzah-A is further subdivided into three members, Members 1 and 2 are comprised of sandstone reservoirs and Member 3 consists of siltstone and shale sediments.
Facies controls on reservoir quality are weak. The main controls on porosity reduction of the reservoir are mechanical compaction and silica cementation. Quartz cementation tends to be the most severe in the cleanest, coarsest sandstones and near certain fractures. The presence of clay mineral grain coatings, although reducing the permeability, but locally protects the rock from secondary quartz overgrowth and preserve the porosity to great depths of burial. Without the grain coating, porosity will decrease with depth until the reservoir rock is completely tight.
Unayzah reservoir seals are provided by the Basal Khuff Clastics, tight Basal Khuff Carbonate and Middle Khuff Anhydrite. The Basal Khuff Carbonate seal does not appear to be regionally extensive but localized and potentially prospect specific. However, there are insufficient data to accurately define the seal for the Unayzah hydrocarbon accumulations.
Due to lack of deep penetrations in Abu Dhabi, basin modeling for Silurian hot shale source rock is challenging. Therefore, much of the unknown source and tectonic information were derived from the surrounding countries. This comes from understanding the regional tectonics and depositional trends of the southeastern Arabian plate, which helped to extrapolate the source trends into the Abu Dhabi area. The basin model shows that oil from Silurian source rock was generated early in the basin history and was widespread by the Late Triassic (220 Ma). Significant gas generation occurred during Lower Cretaceous (140 Ma) and dominated the hydrocarbon system by Middle Cretaceous (110 Ma). During the Early Tertiary (50 Ma), the source rock was highly mature for gas generation and at present-day, the charge is still active in the north offshore of Abu Dhabi.
The pre-Khuff charge history showed that the southern offshore and onshore structures are underfilled. The filling of these structures ranges between 50% and 80%, but in some onshore structures the filling is less than 50%. The middle and northern offshore structures are expected to be filled to spill point.