bluuebunny/crossref_metadata_2025_split huggingface dataset:
Six Sigma Approach to meet Gas Dehydration Unit Optimization
Authors: Al-Adwani Adnan E. , Al-Zuwayer Hamad , Kapavarapu Venkata Madhusudana 
Published: January 2012

Abstract
KOC is having Booster stations facilities to compress the gas from LP and HP pressures to Very High Pressure and transport to KNPC plant for heavier extraction. BS-140 and BS-150 facilities are designed to dehydrate wet gas to 20.90 Lb. /MMSCF and 21.90 Lb. /MMSCF as part of COSTAIN improvements in 1999. BS-140 & 150 facilities are struggling with high glycol consumption and leading to higher operating costs for KOC. In order to provide solutions for the long standing issues like higher Glycol consumption and causing indirect impact on Operating cost of the Process facilities, Six Sigma approach selected for optimizing the Gas Dehydration unit performance in BS-140 facilities.
Team conducted detailed analysis and various process reviews carried out and BS-140 TR-II selected as role model for implementing the operational parameters modifications and monitored the summer period Glycol consumption. Team selected Six Sigma process plan to achieve good results. As part of Six Sigma approach, MAIC (Measure, Analyze, Improve and control) action plan implemented to meet the objectives.
After the improvements resulted 33% glycol consumption reduction (Revenue of US$ 565,049 Approx.)In normal operating scenarios without any business process operations interruption by implementing minor operational improvements.
Ensuring Well Integrity in Deepwater using a fit for Purpose Advanced Cement System
Authors: Taoutaou Salim , Azwar Cinto , Pathak Rakesh , Nzoutchoua Nana Degaul , Ajwani Prakash 
Published: January 2012

Abstract
Deepwater is one of the most technically and logistically challenging environments for cementing operations because of the risks associated with the conductor and surface casing cementing. Understanding the technical challenges, and mitigating the geological risks such as low temperature at seabed and fracture gradient, as well as shallow flow hazards including shallow water flow and gas Hydrates are key to designing cement slurries that can meet deepwater specifications and provide required zonal isolation.
This paper will discuss the real challenges faced during the cementation of critical surface casing for a major operator in India. The maximum operating water depth was 2,965 m [9037.3 ft]. Shallow gas flow, was encountered during the drilling of top hole sections. A low seabed temperature of 2 ºC [35.6 ºF] was also encountered in all the wells, and the narrow margin between the pore pressure and fracture gradient necessitated the requirement of lightweight cement slurry of 1378 kg/m3 [11.5ppg].
All of these challenges were resolved by using an innovative cement system based on Optimized Particle Size Distribution (OPSD), combined with a proprietary low temperature gas migration control additive, used for the first time in India.
The zonal isolation was achieved using the OPSD system and a proper gas migration control additive system.
Advanced Chemical Water-Shutoff Treatments in Multilayer Gas Reservoirs: A Case Study from Peciko Field, East Kalimantan, Indonesia
Authors: Samvelova Marina , Haekal Muhammad , Kristanto Tutus , Kusuma Dadik Hendra , Mahardhini Antus 
Published: January 2012

Abstract
The Peciko field is situated offshore of East Kalimantan, Indonesia. The majority of the reservoirs in this field are gas producers with water. The average production is more than 650 MMscf/D with 11,000 BWPD. The reservoirs are characterized as multilayered sandstone water-sensitive formations with varying permeability ranging from 0.1 md to 2 darcy. The measured depths (MD) of the perforated producing zones extend from 9,400 to 11,100 ft, with an average reservoir bottomhole temperature of 240°F (115°C).
Significant water breakthrough was experienced from some reservoirs, which led to dramatically reduced total gas production per well—up to 90% in recent years (water-gas ratio [WGR] ranging from 100 to 1,000 bbl/MMscf). The goal was to reduce WGR to help prevent the water-source reservoirs from killing the other producing layers and to stabilize the flowing conditions. This could be achieved by shutting off the undesired water production. The main challenge of the field is the number of reservoirs opened per well (&gt;25 perforated reservoirs), with short distances between the perforated zones. Mechanical isolation was impossible in these cases because it would create restrictions during future interventions. Previous bullheading methods using water-shutoff chemicals were not always sufficient because theysacrificed producing reservoirs above. Selective treatment with organically crosslinked sealant gel using an inflatable packer as the upper isolation deployed by coiled tubing (CT) and a retrievable bridge plug used for the bottom isolation was successful in shuttingoff the watered-out sands, while keeping the upper reservoirs producing up to date.
This paper discusses the methodology of the job design, with a detailed operation sequence and results obtained from the field.
Effect of Gas Lift Gas Composition on Production Stability / Instability by Dynamic and Steady State Simulation for Continues Gas Lift Injection Mode
Authors: Maijoni A. , Hamouda A. A. 
Published: January 2012

Abstract
Gas lift is one of the artificial lift methods that is used to increase oil recovery by gas injection into production tubing. At the injection point, chocking effect has been identified as one of the factors that affect production instability. Fluctuation of the injected gas pressure, affects the gas/liquid interface behavior.
Influence of the gas composition on the production efficiency, to our knowledge, has not been addressed in literature as an additional factor that plays role in efficiency. The flow instability leads to discrepancies between the forecasted and the actual production.
The main objective of this study is to address the production instability of gas lift wells in transient (dynamic) and steady state simulations for continuous gas injection regime.
Sensitivity investigations for stability analysis are performed for the various gas compositions, gas injection rates, injection pressure, prudctivity index (PI) and gas lift valves (GLV) port size. The results show that higher gas density, higher gas injection rate, higher injection pressure, higher PI and lower gas lift port size can stabilize the gas lifted well. When, relating the gas composition to density for black oil in dynamic and steady state simulation, it is interesting to see opposite effects are obtained from the results that are obtained these simulations, where dynamic simulation shows that the heavier gas gives larger production rates compared to lower gas density, while the opposite is obtained from the used steady state simulator.
Business and Technology Innovation: Essential Imperatives for Future Energy Sustainability
Authors: Kelechukwu Ekeh Modesty 
Published: January 2012

Abstract
Exploration of petroleum resources is considered synonymous with the lifeblood of modern society and how it meets its energy needs. Yet, the entire globe has been unimaginably seized by the soon visible energy crisis and consequently demanding from humanity a systematic blue print of its sustainability. The future looks very different from our routine hydrocarbon exploration and production practices, hence to succeed in such future, players in the petroleum industry will need innovative business strategy to make their portfolios more diverse; develop new technologies that will help to establish the heartlands of sustainability; globalise operations and best practices; and invest in partnerships that create value across the strata of stakeholders. However, energy sustainability is a complex challenge, which involves, among others; petroleum industry players, private sector and Government. While parallel development in creating business friendly-environment and innovative technological advancement will serve as a vehicle to enable success in future energy sustainability. Technology will significantly influence the availability, choice and cost of future energy. Investment in R&D is crucial to provide energy efficient-technologies through private sector partnership. Business plays an important role in energy efficiency and sustainability, within its sphere of responsibility, in partnership with stakeholders and investment diversification. It should be taken into account that business operates well under sound predictable long term enabling frameworks and good governance. This paper focuses on the opportunities of inventing new conceptual dynamics to ensure sustainable energy Future.
Manifold Production Enhancement through Effective Horizontal Well Placement within a thin Heterogeneous Silty-Sands Reservoir: A Successful Case for the First Time in Wasna Field, India
Authors: Sapkal Arvind Vilasrao , Kar Somenath , Kumar Surendar , Majumdar Chandan , Kumar Rajeev Ranjan , Vashisht T S , Keot Chandan Jyoti 
Published: January 2012

Abstract
Prime objective of horizontal wells is to enhance production by maximizing reservoir contact. Hence it is extremely essential for deviated section to land accurately on top of pay horizon followed by optimum placement of horizontal section. Lateral formation heterogeneity in terms of thickness, lithology and stratigraphic pinching out makes proper horizontal well drilling through deltaic silty-sand reservoir in Wasna field, India; a real challenging job. Absence of Seismic data also adds structural dip uncertainty to the complexity of these targets. Real-time decisions making via optimal well placement technology are useful to drill these wells in a cost effective manner.
In the studied field, several attempts were taken previously to drill horizontal well geometrically but the production result was never encouraging. Manifold production enhancement through accurate horizontal drilling has been achieved using conventional well placement method for the first time in this field. Well Placement workflow involves real time well trajectory designing while drilling based on layer earth model updation using LWD Image and Log data.
The high resolution LWD images in real time have been instantaneously utilized to compute the orientation of the geological features across the borehole with high degree of accuracy. These computed orientations along with real time log data is used to update the near wellbore structural and stratigraphic model. Accurate configuration of subsurface layer earth architecture helped in effective forward designing of the well trajectory.This interactive 24X7 real time process finally enabled the successful horizontal well drilling within 1.5 m thick sweetest part of the reservoir. The well was placed with 95% NTG resulting around 5 times increment in initial production compared to the other existing horizontal well.
This paper illustrates an extraordinary successful case study which opens new and exciting possibilities for horizontal well drilling campaign in the Western Onshore India.
The Contribution Of Synthetic Based, Non-Aqueous, Drilling Fluids To The Successful Development Of Mangala Field, India’s Largest Onshore Oilfield
Authors: Sawyer Graham , Lochhead Ian , McKenzie Tim , Peytchev Peter , Uphadyay Abhishek , Marshall David , Vickers Steve , Kosandar Balraj 
Published: January 2012

Abstract
The Mangala field was discovered in 2004 in the sparsely populated, remote, undeveloped Thar Desert of NW India. Mangala is India’s largest onshore producing oilfield and its development was fast-tracked with production start-up in 2009. This paper describes the process of selection, design, testing, and implementation of specific synthetic-based drilling fluids and their advantages (technical and economic) over conventional water-based fluids.
The field development plan includes 109 production (11 horizontal) and 53 water-injection wells, all directionally drilled from wellpads. Newly-designed, mobile drilling rigs predominantly used rotary steerable systems. Synthetic-based fluids were proved appropriate for drilling all main hole sections with a drill-in fluid system custom-designed for horizontal well sections. Strict environmental requirements imposed restrictions on fluid choice, type, handling and disposal in this delicate ecosystem. Over 18 months of continuous drilling, 3 rigs have drilled 130+ wells using and reusing these muds. Rigs are fitted with Hi-G shakers using selected fine screens to ensure tightly controlled Particle Size Distribution (PSD) and drilling fluids are constantly monitored for consistent specifications. Advantages delivered by these muds include very low fluid invasion, excellent return permeability, low filter cake lift-off pressure and high ROPs. This drives drilling performance and has resulted in worldwide top-quartile benchmark ranking in the industry standard database. Planned casing installations, data acquisition and hole sections have been successfully delivered in all wells. Horizontal wells, drilled with 8.5" reservoir sections and completed open-hole with sand screens have delivered record flow rates for onshore India, up to 14,000bopd. The field is currently on production at 125,000bopd.
These custom-designed synthetic-based drilling fluids have been a major contributor to the successful drilling and completion program at Mangala. The top-quartile drilling performance has achieved significant cost savings while still delivering highly productive wells, including the longest, most productive, onshore horizontal wells in India.
Rate Transient Analysis and Investigation of Unit Slopes in Multistage Hydraulically Fractured Tight Carbonate Reservoirs
Authors: Bello Rasheed O. 
Published: January 2012

Abstract
Carbonate reservoirs constitute about 30% of the world’s most active reservoirs and are thus important. The focus of this paper is on the tight carbonate gas reservoirs that are only economic when produced by completing with a multistage hydraulically fractured horizontal well. A unit slope has been observed on a log-log plot of production gas rate against time. This unit slope and flow regime occurs after the one-half slope indicative of linear flow. The objective of this paper is to investigate these flow regimes and provide a method of analysis.
Numerical simulation is the primary method of investigation employed in this paper. Several runs were made with the following variables: reservoir boundary dimensions, hydraulic fracture spacing, phases, hydraulic fracture length and number of stages.
It was concluded that the appropriate reservoir simulation model which results in the observed flow regimes in actual well data is a bounded rectangular reservoir containing a centrally located horizontal well with transverse fractures contacting the reservoir boundary. The main flow regimes observed are linear flow and Unit Slope Flow Regime (USFR). Linear flow occurs with drainage from the reservoir matrix into the transverse fractures. The USFR begins when there is interference between the hydraulic fractures and ends when the fractures drain the reservoir as a unit. The appearance of these two flow regimes, either singly or with the linear flow preceding the USFR, is controlled by a critical fracture spacing. An equation is derived for analysis of these flow regimes to obtain useful reservoir properties for characterization.
Visualization and Analysis of Interaction of Carbonate Reservoirs with Carbon Dioxide During CO2 Enhanced Gas Recovery Process
Authors: Odi Uchenna , Gupta Anuj 
Published: January 2012

Abstract
This paper presents simulation based analysis for CO2 Huff-n-puff and Enhanced Gas Recovery (EGR) process in carbonate rocks that are representative of the Middle East’s aquifers and oil/gas reservoirs. The objective of this study is to study the development of condensate in the near wellbore region of a wet gas carbonate reservoir and to subsequently study the feasibility of using CO2 injection for removing this condensate phase.
Changes in oil saturation, gas saturation, gas permeability, and gas productivity were used to quantify the effect that CO2 has on wet gas carbonate reservoirs. Carbonate reservoir systems have complex structures and to represente these, two reservoir models were constructed that had the characteristics of typical carbonate reservoirs.
Condensates appeared in wet gas systems once the pressure reduces below the dew point pressure. This can be remedied in two ways: (1) repressurizing the reservoir above the dew point and (2) lowering the dewpoint pressure by changing the fluid properties of the reservoir fluid. Both of these remedies can be achieved by using CO2. Results show that CO2 has the ability to repressurize a reservoir and the ability to lower the dew point of a wet gas fluid. Results also show that carefully timing the start of CO2 injection and its duration can significantly improve the economics of enhanced gas recovery process.
Brazeau River Nisku "A" Pool Oil Volume Re-Calculation: A Case History Study
Authors: Chen Andrew 
Published: January 2012

Abstract
The Brazeau River Nisku "A" pool is located approximately 150 km southwest of Edmonton, Alberta, Canada. It has produced 45 °API light oil since 1978 from the pinnacle reefs of Later Devonian Winterburn group. The stock tank oil initially in-place (STOIIP) was estimated from the 2D seismic data to be 33 million bbl. The primary oil production of the under-saturated reservoir pool only lasted two and half years before a dry-gas cycling pressure maintenance scheme was initiated to enhance the pool’s recovery. An infill horizontal well was added in 1992 to the existing two vertical producers, with one-injector to re-inject the produced lean gas back to the reservoir pool from the top of the reef structure, enhancing the pool recovery from a typical gravity drainage mechanism. After 1995, the dry gas injection stopped and the reservoir began pressure blowdown and resumed depletion drive production. By 2010, the pool’s pressure was near a complete depletion. However, the Nisku "A" pool’s performance history data have suggested that 7 bcf more natural gas was produced than expected, raising questions about the long established STOIIP estimate. Numerical simulation studies also failed to reconcile the oil volume estimate conflict between the production performance data and the seismically well-defined volumetric evaluation.
This paper demonstrated, by carefully examining the reservoir appraisal data that the Nisku "A" pool most probable STOIIP is 40 million bbl, instead of 33 million. The 7 million barrels of oil in-place estimate gap could have been easily identified in the first two and half years of production by correctly performing simplistic material balance analysis of the pool’s pressure versus oil and gas rate history and the reservoir compressibility values, which are often taken into granted by engineers in resource and reserve evaluations.
Introduction of a Modified Rotary Steerable System in Papua New Guinea Improves Drilling Performance in Poor Quality Wellbores with Tectonic Breakout
Authors: Dow Michael , Schmickl Christopher , Ross Angus , Baggio Dion 
Published: January 2012

Abstract
Directional drilling in the Highlands of Papua New Guinea is extremely challenging, especially in the intermediate 12!" hole section. 12!" drilling is through medium strength claystones, where severe tectonic breakout occurs. This results in an extremely poor quality, ledged, ovoid, over gauge wellbore. Traditionally positive displacement motor (PDM) bottom hole assemblies (BHAs) were used to directionally drill in these difficult hole conditions. Drilling performance was far from ideal. Steering penetration rates were typically 50–80% less than those obtained when rotating, even at low inclination, with weight stacking, hang up and motor stalls becoming progressively worse with depth. Additionally, the motor pressure drop placed a hydraulic limitation on flow rates. This limitation handicapped hole cleaning optimisation, which was critical if the abundant large 1–3" cavings generated by wellbore breakout were to be removed from the hole.
An initial attempt to introduce a rotary steerable system to improve penetration rates and hole cleaning had been unsuccessful. It was only with the innovative introduction of a rotary steerable system originally designed for soft formations that success was obtained. Modifications to the original system specific for this new environment brought further performance improvements. Performances will be analysed from a series of wells in Papua New Guinea to demonstrate the improvement obtained by the introduction of this new directional drilling technology. ROP improvement, dogleg capability and improved drilling hydraulics will be presented.
Case Study: Cyclic Steam Stimulation in Sihapas Formation
Authors: Putra Eldias A. , Rachman Yusni A. , Firmanto Tri , Arsyadanie Robbie , Hafizh Gama 
Published: January 2012

Abstract
Viscous and heavy oil reservoir is a challenge in oil production due to unfavorable mobility ratio. Thermal injection is a method to increase well productivity and oil recovery which is usually performs in shallow reservoir. One type of thermal injection is cyclic steam stimulation.
Cyclic steam stimulation was conducted in two wells of Melibur field as a pilot project. Since it has 8–12 cP viscosity, 22–26° API oil gravity and relatively shallow reservoir depth, Melibur has an appropriate character to perform steam injection.
The project started with well selection with the main consideration is amount of remaining oil in reservoir. It is also considering completion diagram and operational aspect for each well. The injection process was performed in 10–12 days with certain injection parameter to meet the heat requirement for reservoir and follow with 5 days soaking.
This paper focuses on the result and effect of cyclic steam stimulation to well and offset wells production rate and fluid properties. Many experiences acquired from the project of cyclic steam stimulation perform in Sihapas formation, one of them is the effect to offset well that indicates there is a connection and high heat conductivity between wells. Incremental of initial production rate about 40% occurred in first well. In second well, this operation gives an effect to offset well with the incremental of production rate reach 100% in nearest well. Oil properties changes with different in viscosity, oil gravity and pour point value after cyclic steam stimulation.
Pressure Drop Prediction in Deep Gas Wells
Authors: Moradi B. , Awang M. Bt. , Shoushtari M. A. 
Published: January 2012

Abstract
Deep reservoirs with very high temperature and pressure are turning to be the main development sites today unlike in the past. Normally these reservoirs contain sour gas. To run measurement tools such as wireline logging are very costly, and because of sour gas rapidly corrodes wirelines it may also be disastrous.
In this paper, effect of heat transfer is studied on pressure profile in deep gas production wells.
The mass, momentum and energy balance equations govern the fluid flow in the wellbore. Wellbore governing equations are solved simultaneous and consequently a procedure is developed to calculate pressure and temperature profiles in deep gas wells.
Result indicated pressure drop is sensitive to temperature profile and there is showed how temperature profile can affect on pressure drop in the wellbore.