bluuebunny/crossref_metadata_2025_split huggingface dataset:
Utilization Of Innovative Technologies To Meet Increasing Oil Demand
Authors: Zorbalas Konstantin , Alomrani Majed Mohammed , Saeed Saeed 
Published: February 2016

Abstract
In an effort to improve well production performance targeting recent increases in oil demand, Saudi Aramco implemented several innovative technologies and practices in its offshore assets in the Arabian Gulf. The identified challenges which followed past practices were focused on enhancements to existing well completions, chemical treatments of damaged wells, implementation of Smart field technologies and early detection of casing leaks to enhance wellbore integrity and meet environmental standards.
This paper describes the methodologies of four technologies which were tested and implemented in three major offshore fields in Saudi Aramco. These technologies are the use of passive inflow screens combined with swellable packers in horizontal sidetracked wells to prevent premature water or gas encroachment, smart in-situ gas lift completion which utilizes the reservoir gas cap for artificial lift of oil wells, the chemical treatment of wells which endured formation damage and the utilization of a modified ultrasonic tool for early casing leak detection in aged wells equipped with up-hole packers.
All these technologies proved to be successful and their combined application added value to Saudi Aramco's operations. As a result, the production targets for 2006 were met and the positive results obtained from the implementation of these technologies will lead to the optimization and improvement of future operational practices.

Background
Saudi Aramco operates three major offshore fields in the North part of the Arabian Gulf and horizontal drilling in these three fields is dated back to more than a decade. The company has been prudent in evaluating the technology of drilling and completing horizontal wells as it was progressed with time and constantly improving the designs of horizontal completions to maximize reservoir recovery. As the number of horizontal wells increased in the fields, the reservoir sweep efficiency is improved with time and higher production rates were accomplished on a per well basis when compared to vertical producers.
The geology in one of the fields is rather complicated with the existence of stringer sand bodies which are usually separated from the main sand by an impermeable shale break (Figure 1). The stringer sands were deposited uncontrollably in the subsurface and pose enormous challenge in the well placement and deciding on the direction of the wells when it comes to horizontal drilling.
The three major offshore fields were discovered in the mid-fifties and have been on production since then. Their petrophysical properties are characterized by clean coarse sands with very good permeability in the range of 3–5 Darcies (D). The recovery mechanism is by natural water drive and in some areas it is complemented by a gas cap drive. The sandstone reservoirs have pressure support by a strong water aquifer, which underlains the sand bodies.
Derivation of Relative Permeability and Fractional Flow Behaviour From the Inversion of Saturation Logs in Horizontal Wells With Application to Water Shut-Off and Predicting Volumetric Sweep Efficiency
Authors: Harris Jeremy 
Published: February 2016

This reference is for an abstract only. A full paper was not submitted for this conference.

DESCRIPTION
An inversion method is presented that uses saturation log profiles recorded in horizontal wells to derive relative permeability and fractional flow properties for a waterflooded carbonate reservoir. Observed water saturation profiles decreasing horizontally away from hydraulically conductive faults suggest a line-drive type encroachment of water into the fault-bound matrix blocks. The waterfronts have produced saturation profiles analogous to that predicted by Buckley-Leverett displacement theory, including the characteristic shock front. These profiles record parameters such as irreducible water saturation, the shock-front saturation, average saturation behind the front, and the residual oil saturation. These parameters are used to define boundary conditions on a fractional flow plot using Welges method. A fractional flow curve which meets the boundary conditions is then derived by changing the shape of the controlling relative permeability curves. The observed saturation profiles also show a correlation with porosity, allowing a suite of scanning curves to be derived for each porosity class. The reliability of the method is demonstrated by plotting the average pulsed-neutron-capture log saturations at the perforations against the producing watercut at the time of logging on the fractional flow graph.

APPLICATION
The fractional flow curves are used to discriminate between wells that produce at the correct watercut from wells that could benefit from water shut-off. The curves are also utilised for forecasting waterflood performance.

RESULTS
Identification of additional perforation and water shut-off activities amounting to significant oil gains over the past three years from very mature well stock. Provided new insight into the oil displacement process inferring higher mobility to water than previously suggested from core-plug data. Improved modelling of well & reservoir performance.

SIGNIFICANCE
First time that nonsynthetic saturation-front profiles are presented in the literature and used to derive dynamic properties.
Developments in the Magpore Method for Characterising Pore Fabrics and Permeability Anisotropy in Clastic and Fracture Reservoirs
Authors: Hailwood Ernie 
Published: February 2016

This reference is for an abstract only. A full paper was not submitted for this conference.
The magpore method determines the pore fabric of sediment samples by saturating the pore network with a magnetic fluid, then using anisotropy of magnetic susceptibility (AMS) measurements to define the preferred orientations of pore long and short axes. The full 3-D permeability anisotropy of the sample can be predicted from the results, particularly the anisotropy degree and directions of maximum and minimum permeability. The reliability of the method has been confirmed by comparing magpore data with directly-measured 3-D permeability anisotropy on sets of test samples. Examples will be shown that illustrate applications of the method to determining matrix porosity anisotropy in a range of different hydrocarbon reservoir facies. Results demonstrate that, in addition to the well-documented difference between vertical (KV) and horizontal (KH) permeability, many formations also exhibit azimuthal permeability anisotropy (ie variations in KH) of 10 to 20% or more, which is large enough to exert a significant influence on the fluid-flow properties of the reservoir. A particular attribute of the magpore method is that 3-D pore fabric measurements can be made directly on individual samples ranging in size from a few mm to several cm and on groups of samples spanning several metres or more. Thus, the method can provide permeability anisotropy data on spatial scales ranging from individual thin beds to metre-scale sand bodies. Applications of magpore for characterising microfracture fabrics in fracture reservoirs will also be illustrated. Laboratory loading experiments monitored by magpore measurements demonstrate that penetrative microfracture fabrics may develop at applied stresses well below the catastrophic failure stress of the rock (at which visible mesofractures appear). These microfracture networks can be characterised by the magpore method and potentially make a significant contribution to the porosity and permeability properties of these reservoirs.
Numerical Computation of Mitigation and Extinction of Large Scale Fires by Water Mist Systems
Authors: Magnussen Bjorn Fossmo , Evanger Trond , Grimsmo B. , Lilleheie Nils Inge 
Published: February 2016

Abstract
Water is an efficient and environmental friendly means to mitigate and extinguish fires. However, it is not easy to judge the efficiency of water based mitigation and extinction systems due to complexity of the physics and geometry. Therefore advanced computation systems, like Kameleon FireEx KFX®, must be utilized for a prediction of the interaction between the fire, its environments and the water droplets.
Generally water droplets do not extinguish fires in the gas phase. When water droplets hit a fuel-emitting surface like a pool of hydrocarbons, or a burning surface material, then the fire may become extinguished. Water droplets and water vapour do, however, have a mitigating effect on both kinds of fires due to the screening of radiative heat transfer.
Water droplets can also extinguish fires in the gas phase when they become small enough, i.e. in the size range of 100 µm because then they become small enough to interact with the reacting structures in the flame, which are in the same size range. Water mist systems are extinguishing systems of this kind.
The basic physics related to fire evolution and the interaction with water droplets is discussed, including droplet movement, evaporation, radiation screening, spectral effects, extinction, droplets interaction with fire engulfed objects etc.
The paper includes extensive demonstration of computational studies performed for the oil and gas industry. These computations have had major impact on fire strategies and technical solutions on installations worldwide.

Physics of fires
Due to buoyancy forces created by the big temperature differences, the flow pattern in a fire is turbulent. The turbulence is characterized by vortices in a wide spectrum of sizes, ranging from the dimensions of the linear scale of the fire down to, and even smaller than, the so-called Kolmogorov scales. This means from meters down to fractions of a millimeter. The mechanical energy of turbulence, k, is created through the interaction between the mean flow and the turbulence. While the production of k takes place in the larger scales of turbulence its dissipation takes place in the smallest vortices in the fine structures of turbulence, where the molecular mixing takes place. This is consequently the domain for the chemical reactions.
The above is inherent in turbulent combustion in general whether it is in fires, gas turbine combustors or piston engines.
Figure 1 shows a cut through a laminar diffusion flame taken by the Laser Induced Fluorescence technique (LIF) depicting a reacting specie. Figure 2 is a similar cut through a premixed turbulent flame.
Integrated Subsurface Geology and Biosteering: A Case Study From the Sajaa Field, Sharjah, UAE
Authors: Marshall Paul Robert , Burchette Trevor , Ali K.S. 
Published: February 2016

This reference is for an abstract only. A full paper was not submitted for this conference.
A case study is presented to show how close integration of continual subsurface geological insight and wellsite biosteering data generation and interpretation played a key role in ensuring commercial and technical success of the underbalanced, coiled tubing drilling (UBCTD)campaign at the mature Sajaa gas/condensate field. Reservoir pressure depletion had led to UBCTD being required to increase both rates and reserves. Commercial and technical success was known to depend heavily on maximisation of reservoir exposure in the multiple target intervals within Thamama Group limestones. The field presented complex geology: major and minor folding and faulting; lateral facies variations; problems in field boundary delineation. Despite exhaustive efforts, seismic interpretation was unable to provide sufficiently precise resolution for well planning and monitoring if the aim of maximised reservoir penetration was to be achieved. As the campaign progressed, the key role played in achieving the aim by the integration of subsurface geology, realtime GR and wellsite biosteering (analysis of fossils and limestones from extremely small cuttings samples) was increasingly recognised. Continued development of office- and wellsite-based techniques during drilling of 164 laterals in 28 wells led to optimisation of reservoir penetration in ways and to extents considerably beyond those initially anticipated. Optimisation was achieved as: high percentage of borehole length in target; extension of achievable reach (beyond initially believed limits); curtailment of drilling for unachievable targets; realignment of boreholes encountering unpredicted geological complications (including poor target parameters); and by rapid re-planning of later trajectories based on interpretations obtained during drilling. Accumulated information was used during and after the campaign to: modify plans; generate new plans; improve geological understanding; reassess the completeness of the campaign; and form the basis of the proposal for a further campaign. Successful application of this technique with great future potential has continued elsewhere in the region.
Getting the Last Gasp: Deliquification of Challenging Gas Wells
Authors: Bondurant Alison Vergari , Dotson Bryan Dale , Oyewole Peter Olugboyega 
Published: February 2016

Abstract
A common characteristic of "challenging" unconventional gas resources, namely low permeability sands, shale and coal bed methane, is that the ultimate recovery is dependent on economic removal of liquids accumulation, generally termed "deliquification". This resource is making up an ever-increasing part of the North American gas supply. Since there is no one "perfect solution", and the problem affects thousands of wells, the opportunity involves not only technology development but also knowledge management and building resource capability.
This paper outlines the scope of impact and opportunity in North America, followed by the industry's approach and progress in the arena. The North American industry is working a variety of deliquification technologies for "challenging" gas, with developments ranging from adapting existing oil-field technologies, to developing gas-specific technologies, to "on the horizon" technologies. Examples in each stage of the development process will be shown.
The effective communication of these developments to operators and suppliers is also a necessary component. The industry-wide annual conferences that have emerged in the last seven years are the primary avenue for this communication, and are supplemented in some cases by operator internal networks.
This combination of technology development and effective communication is increasingly allowing North American operators to maximize the recovery of challenging gas resources.

Context

Economic Context.
North America is one of the largest natural gas markets in the world, and is supplied primarily from domestic production. In 2006, North America (Canada, Mexico and the United States) produced 73 BCF/d and consumed 74.5 BCF/d (1); this represents about one quarter of the world gas supply and demand.
A distinguishing characteristic of North American land-based gas production is the large number of low rate wells. For example, in the continental United States, the majority of gas wells produce less than 100 Mscfd. Figure 1 shows the well count distribution for a significant portion of United States gas production. The low rates reflect the maturity of North American gas production and the predominance of "challenging" production from low permeability sands (less than 0.1 mD), shale and coal bed methane.
Figure 1: Gas rate distribution for North American gas wells.
Low rate gas wells almost always cease production due to liquids accumulation in the wellbore. Consequently, deliquification of low rate gas wells is of great importance to North American gas producers.
Coupled with this technical challenge is that the scarcity of gas in the market has increased gas prices substantially in the last 10 years. As shown on Figure 2, wellhead gas prices have roughly tripled in the past 10 years (2). Consumers are providing the economic incentive to produce low rate gas wells beyond the natural flow of the well.
Improving Oil Recovery through Integrated Reservoir Management In A Mature Oil Field In The Middle East
Authors: Chouhdary Muhammed Akram , Al-Rasheedi Hussain Rakeb , Wani Mohamad Rafiq 
Published: February 2016

Extended Abstract
Paper illustrates that how the application of innovative technology and principles of integrated reservoir management can improve recovery efficiency in a mature oil field. The paper discusses key principle of effective reservoir management. Effective reservoir management is a combination of capability, viability and processes. The application of the principle is illustrated with an example of a case study of Wafra Ratawi reservoir, a lower craterous Oolite reservoir is in a giant mature oil field Wafra.
The field was discovered in 1954 and is located in the Neutral Zone between Kuwait and Saudi Arabia. The mineral rights in this region are shared equally by both countries. The field is now operated jointly by Saudi Arabian Chevron (100 % owned subsidiary of Chevron) and Kuwait Gulf Oil Co. The reservoir is an anticline with 2 lobes East Wafra and Main Area. The reservoir has varying oil gravity with low bubble point pressure. The Production from this reservoir started in 1957. The field was shut in during the first Gulf war, and the increase in average reservoir pressure was observed, signaling for existence of partial aquifer support.
After an extensive geologic and engineering study, the production strategy to produce above the bubble point pressure was adopted. However, because of the weak aquifer support, the reservoir pressure started to decline rapidly. The simulation model in 1995 indicated a significant opportunity to enhance the asset value through recovery improvement (IOR) techniques.
Based on the sound reservoir engineering practices, detailed reservoir studies, low cost and higher economic benefits the peripheral water injection was selected as preferred method for initiating reservoir pressure maintenance. The pressure maintenance project (PMP) was implemented in 1998. The Pressure Maintenance Plant was designed to handle all produced waters in the Wafra field with varying salinity and H2S contents.
A depletion strategy objected at optimum reservoir management and maximum oil recovery was adopted. Following are the key features of depletion strategy.Target Injection ratea) Phase -1 Injection/Production rate &gt; 1b) Phase-2 Injection/ Production rate ~ 1Maintain Optimum Draw Down in producing wells.Take maximum benefit of water front movement.Manage problems related to vertical permeability distribution.
Investigation of Miscible Gas Flooding in North Kuwait Reservoirs by Experimental and Modeling Approaches
Authors: Al-Mayyan Haya Ebrahim , Al-Anzi Ealian H.D. , Al-Ajmi Moudi Fahad 
Published: February 2016

This reference is for an abstract only. A full paper was not submitted for this conference.
The North Kuwait (NK) long term strategy is designed to increase its oil production as per Kuwait Oil Company (KOC) development plans. North Kuwait's production to date is characterized by large, massive reservoirs undergoing natural depletion supported by strong natural aquifer drives and, in some reservoirs, natural aquifer support is supplemented by waterflooding. In order to maintain production, the current primary and secondary (waterflood) recovery mechanisms must be advanced into secondary and tertiary (EOR) in the main NK reservoirs. To date, there is zero EOR production from KOC reservoirs. Very limited lab work has been conducted with majority of it on NK reservoirs. These experiments include (1) Swelling tests, (2) Slim-tube tests, (3) Composite core immiscible tertiary Gasflood. This study is the first to define a comprehensive EOR lab studies in a systematic manner to assess the EOR potential in NK. The study focuses on gas injection EOR option, as more than 90% of NK reservoirs are suitable candidates for this method. The injectant gases considered are pure and impure CO2, N2, and hydrocarbon gases. This paper presents a review of the previous lab work, and recommend to perform additional laboratory tests for each major reservoir in NK. Specific attention is focused on KOC limited gas injection experiments. These tests have been a useful tool for EOR screening of NK reservoirs, as: Equation of State (EOS) has been developed and used for simulation these injection studies,One-Dimensional (1D) slim-tube compositional simulation models were built using the matched EOS to validate slim-tube test data,Additionally, the available Minimum Miscibility Pressure (MMP) correlations were used for comparison.
The paper also presents the approach to predict the MMP of NK reservoir fluids with various injection gases other than the gases used in the actual experiments.
Angudan Revisited: - Using Old Data To Explore for New Targets in a Frontier Area
Authors: McIlroy James Graham 
Published: February 2016

This reference is for an abstract only. A full paper was not submitted for this conference.
Newly acquired modern long-offset 2D seismic data in conjunction with gravity and magnetic data has provided a more complete picture of the deep prospectivity of the South Oman Salt Basin. Deeper potential that was poorly imaged previously is now targeted to unlock future potential for the Block. The Angudan area of the South Oman Salt Basin was first explored in the 1960's using surface geology and low-fold seismic data. This resulted in several shallow wells that tested seismic-delineated structural closures. The failure of these wells lead to a shift of exploration to the more prospective and more successful areas in Northern and Central Oman during the following years. The discoveries in the 1980's refocused exploration to the South where the Ara carbonate stringers proved to be a valid and prolific reservoir. Although the Angudan area was revisited with improved seismic coverage, the data was not of sufficient quality to resolve the deeper horizons. The Angudan-1 well drilled in 1990 penetrated the deepest mappable marker but failed to find any reservoirs. It stopped short of the Ara carbonates. As focus has shifted again to the South in the last few years, the deeper South Oman Salt Basin reservoirs were targeted using long offset seismic data and a 2D grid down to 1 km spacing. Although the rugged terrain and various access issues in the area caused access restrictions, an improved image of the Ara carbonates has been obtained. A combination of geophysical techniques has reduced the exploration uncertainties in this frontier area and improved our prospect risk assessment.
New Exploration Play in Basal Burgan Unnamed Clastics, Kuwait
Authors: Thakur Sanjeev S. , Kumpas Michael George , Al-Darmi Areej 
Published: February 2016

This reference is for an abstract only. A full paper was not submitted for this conference.
Unnamed clastics at the base of Burgan offer a hitherto un-explored hydrocarbon play in onshore Kuwait. It is a sub-unconformity play and comprise a composite sequence with three systems tracts upwards, namely; transgressive, highstand and followed by another transgressive package. Thickness of whole package varies between 10 and 145' (generally between 37'to 60', net pay 40'). Sand bodies in the transgressive system tracts are discontinuous laterally and vertically and that of the highstand system tracts are fairly continuous sheets and shale-out in the distal settings. Thin channel sand bodies of lower transgressive and highstand units entrap oil whenever upper transgressive unit provides effective top seal. The effectiveness of the top seal depends on the vertical limits of incision by overlying lowstand Burgan clastics. The trapping is controlled by both stratigraphic and structural components. In most of the wells targeting Lower Cretaceous or deeper, casings are generally set within this unit, often proper logs are not run across the section. However, some of the wells have partial suit of logs and well cutting. The resource remained largely unaccounted and unexplored. The play has been identified in Ratqa, Mutriba, Medina and Raudhatain areas. A case study is presented from the Raudhatain Area.