bluuebunny/crossref_metadata_2025 huggingface dataset:
Natural Down Hole Gas Separation for ESP wells
Authors: Al-Hassan A.. , Kumar P..
Published: October 2015

Artificial lift is widely used by Kuwait Oil Company (KOC) to both accelerate and increase oil production. The electrical submersible pump (ESP) is one of the most commonly used artificial lift systems in oil and water wells. The ESP is a multistage centrifugal pump placed down in the wellbore, capable of delivering high pressure increments for large oil rates. Reservoir oil is always saturated with natural gas, which will be separated from the oil as the pressure is decreased below the bubble point pressure. Since oil production is based on pressure drawdown, ESPs are likely to experience free gas in the suction fluid. Due to free gas present, several gas locking and ESP trips are observed. This technology is taken into consideration to minimize the free gas produced into the pump. Application of this technology can lead to more stable flow, less ESP trips and increased its run life of ESP. More over, suitable cooling mechanism has to be set up for the motor protection.
An Integrated Approach for Sustainable Development of Mature Field Using IOR Techniques: A Case History of Oligocene Sand of Upper Assam Basin, India
Authors: Kumar Manish , Yomdo Saloma , Pandey Ashutosh Narayan
Published: October 2015

Sustainable development of a mature field depends on various factors, which can be categorized into well level and reservoir level. This paper is a summary of experience of various techniques used at well level and reservoir level. The objective is to sustain/increase the level of oil production and reduce watercut using various completion methods & pressure maintenance.

This Paper will elucidate a Field Development Plan for a mature field. Several possible options were tested like 1. Possible workovers 2. Combination of Horizontal and Vertical wells based on firm and dependent locations 3. Infill short lateral wells 4. Optimal production rate to minimse pressure decline by limiting the gas production and hence putting a check on GOR 5. Water injection strategy 6. Intelligent Oil Field Completion using ICD (Inflow Control Device). For the purpose of testing the best possible course of action; the reservoir was modeled and history matching was done with satisfactory results. Prediction Strategy was then deployed at simulation stage. The financial analysis for all the prediction scenarios were also carried out using Net Present Value (NPV) method to check the feasibility as well as profitability of the various envisaged Production Strategies.

Based on the analysis, the maximum recovery was obtained from a combination of infill wells and ICD completion, but on monetary grounds, the best case consists of workovers and horizontal wells to tap the oil from segregated pockets. In the end, a comprehensive and extensive comparison of all the possible way-through options are discussed with pros and cons of each one. A sensitivity analysis was performed on economic parameters (e.g. crude oil price, operating cost, Taxes, Royalty, capital expenditures) to analyze impact on various economic indicators.

This Paper presents novel ideas into the ever expanding sphere of Field Development. It presents an extensive review of the various aspects of mature field development and their economic analysis. The field in discussion is Makum-North Hapjan which contributes around 40% of total production from OIL's fields in North-East India. It has been under production since 1993, with 62% of the production coming from horizontal wells.
Successful DST Methodology Adopted in Highly Deviated, Deep, Sour & HPHT Exploratory Well: A Case Study
Authors: Al-Ibrahim Abdulla , Al-Bader Haifa , Al-Salali Yousef , Duggriala Vidya sagar , Ayyayo Manimaran , Subban Packirisamy
Published: October 2015

Exploration in the state of Kuwait focuses on finding light oil and gas from deeper, HPHT and naturally fractured tight gas and condensate Jurassic Reservoirs. These reservoirs are drilled with high Oil Base Mud (OBM) densities (16–20.8ppg). The existing surface and subsurface constraints resulted in changing the proposed well location, which resulted in changing the well profile from vertical to highly deviated well. Having a deep HPHT well in highly deviated manner causes more complexity while drilling and testing the Jurassic formations. 78.2-degree angle deviated well with several side tracks and two doglegs was drilled to a depth of around 20,000-ft.(MD) to delineate the potential of the deep reservoirs. Well intervention operations were considered potentially risky due to the presence of hazardous well conditions such as HPHT and high H2S concentration. Keeping in view of well profile and hostile environments, it was very challenging task to conduct a short term well testing (STT) in these deep reservoirs.

Tractor was used in the highly deviated sections with more than 50-degree angle to record the cement quality logs with Wireline. The target formations were perforated using high temperature and high shot density TCP guns in overbalance condition using drill-pipe. Two separate Drill Stem Tests (DST) consist of tester valve, multi-cycle circulating valve, two rupture disc valves, Down hole sampler and Down hole memory gauges were used to test two different deep high pressure and sour reservoirs. Using of 15 K Coiled Tubing with total length of 20,000 ft for well activation and stimulation assisted the well intervention during the STT.

Careful planning, proper selection of equipment & materials, detailed well test program and procedures resulted in a safe and successful testing operations in such extreme well conditions such as unconventional well profile, HPHT, and presence of H2S. For the first time in Kuwait, a highly deviated exploratory well with complete set of DST tools was successfully tested and proved significant amount of light oil and gas from a hostile reservoir.

This paper describes and discusses the challenges encountered while drilling and testing an exploratory well and the achievement of overcoming these challenges which leads to successful well testing.
Shrouded ESP with Y-tool Enables Virtually Unlimited Access to Completion Interval for Well Intervention and Surveillance Operations
Authors: Anthony E.. , Al-Mutawa M.. , Al-Sharhan G.. , Jha A..
Published: October 2015

Deviated wellbores are more common-place in the industry in recent years as Maximum Reservoir Contact (MRC) is the preferred strategy in wellbore construction. These high-angle, tortuous wellbores, however, have now limited the artificial lift options to Electric Submersible Pumping systems which are capable of sustained life cycles in high-watercut, low-pressure, and/or low-rate completions. Production logging and Coiled Tubing intervention in multi-layered completions and/or multi-compartment horizontal laterals equipped with Electrical Submersible Pumping systems has customarily been a major challenge, especially when the bypass fluid velocities are below the motor-cooling threshold for a conventional Y-tool configuration.

An innovative design comprising of a shrouded Electric Submersible Pump with Y-tool combination is able to facilitate access to any completion that requires production logging and/or CT intervention. At relatively low fluid rates, the shroud over the Electric Submersible Pump increases the fluid bypass velocity alongside the submersible motor for the required cooling. This shrouded Electric Submersible Pump configuration is conventionally used where the production flow rates within the wellbore are insufficient to generate the fluid bypass velocities necessary for optimum motor cooling. The Y-tool in other completions allows access for any type of wireline or Coiled Tubing-conveyed intervention for surveillance and and/or treatment operations. Previously, if a completion required a shrouded ESP, conventional Y-tools were precluded, due to the limitation of the production casing inner diameter. A specialty Y-tool was designed to accommodate conventional bypass tubing that has sufficient internal clearance for standard wireline tools together with a crossover adapter for the ESP shroud.

This combination of conventional bypass tubing and Electric Submersible Pump shroud in the same wellbore, is limited to 9⅝″ casing where the shroud outer diameter and the bypass pipe outer diameter must have sufficient clearance between each other and sufficient stand-off from the inner diameter of the production casing. The Electric Submersible Pump shroud ensures optimum motor cooling and extended system run life, especially at lower flow rates.

This innovative technology is now scheduled to be standard equipment in all Electric Submersible Pump completions in production casings with Outer Diameter equal to or greater than 9⅝″. Diagnostic wireline and Coiled Tubing-conveyed surveys, remedial and stimulation treatments can now be performed thru-tubing in Electric Submersible Pump completions without costly rig workovers. The availability of these services affords timely intervention to arrest increasing watercuts in Waterflood offtake producers thereby reducing the overall baseline production decline rate.
Contractor Safety Management
Authors: Chakrapani Ravi , Al-Qallaf Yousef
Published: October 2015

Oil and Gas processing operations comprise of numerous activities that are hazardous in nature including dangerous equipment and harmful process fluids. Contractors are the key and major work force in all construction projects in Oil & Gas sector. Managing Contractors' Safety has become extremely challenging in view of the large number of contractors' work force deployed/spread over many oil fields for execution of various projects including strategic / complex in nature and importance. Being an industry leader of the Kuwait state and with an objective of becoming regional leader in Middle East, Kuwait Oil Company (KOC) is working to manage the issues related to contractor Safety Management effectively. West Kuwait (WK) fields in KOC are situated in the desert areas predominantly and comprises of oil fields such as Umm Gadair, Minagish, Dharif, Abdaliyah etc. The operations spread over these fields make it really challenging in managing the contractors and their HSE performance.

In order to improve and sustain the progress of Contractor safety Management, a systematic approach process was developed to evaluate and monitor by adopting various themes/aspects involving all levels of KOC Management in line with the Company's HSEMS procedures/Standards applicable to construction worksites and site offices of West Kuwait projects and contractors.
Continuous Operation Model for Tight Gas Development in Sulige Gas Field, China
Authors: Naizhen Liu , Ming Liu
Published: October 2015

Sulige gas field of China is a typical tight gas reservoir with the features of low-pressure, low-permeability and low-abundance. During almost twenty years of development, low production and high cost are the two most important elements which hinder its quick development. In the beginning, vertical wells are the main well type used in the gas field. However, large number of collected data and analysis from the vertical wells shows that horizontal well can be more effective. To pilot the development result of horizontal wells, several pilot zone and blocks are selected. In the second half of the twenty-first century's first decade, horizontal drilling and completion have been widely used in this field. Considering the advantage of horizontal wells compared with the vertical wells, gas production has been substantially increased.

With the success of shale gas development in North America, many of advanced technologies and management skills have been frequently applied to other kinds of oil and gas field, tight gas, tight oil, etc. Due to the job complexity and economic expense, technical skills and management experiences have been significantly improved, which is beyond everyone's imagination, especially for the cognition of unconventional resources, development methodology, intersecting job procedure, etc. All these improvements ensure the breakthrough of development in Sulige gas field in the last 5 years.

This paper aims to describe the application of continuous operation model, which is also called factory operation model, in block Su53 of Sulige gas field from the technical point of view. First, the background of block Su53 will be introduced, including geological characteristics, formation property, development history, etc. Second, continuous operation procedure will be described, which covers the intersecting operation among several kinds of specialties. Third, the successful application of continuous operation model in pad Su53–82 which includes 10 horizontal wells, 2 directional wells and 1 vertical well and the applied technologies will be introduced. Finally, we compare the gas production and economic benefits with the regular wells.
An Overview of Different Chemicals Used in Designing Cement Slurries for Oil and Gas Wells
Authors: Al-Yami Abdullah S.
Published: October 2015

Cement must be designed in a way to ensure acceptable properties such as mix ability, stability, rheology, fluid loss, and adequate thickening time. Different chemicals are used when designing cement slurries. These chemicals are used as retarders, fluid loss additives, dispersants, gas migration additives and expansion additives.

Typical examples of compounds used as retarders include: calcium lignosulfonate, sodium lignosulfonate, sodium tetra borate decahydrate (borax), starch derivatives, hydroxyethyl cellulose and weak organic acids. Examples of dispersants are ferrous lignosulfonate, acetone, and polyxythylene sulfonate. Many additives for fluid loss are water soluble polymers such as Vinyl sulfonate based on the 2-acrylamido-2-methyl-propane sulfonic acid. To the best of the author's knowledge, there is no study that compares the performance of different chemicals in cement designs.

The objective of this paper is to detail some of the cement chemistry and to go over the chemicals used in cementing oil and gas wells and their mechanisms of actions.
Building Safety Culture within Novice Engineers
Authors: AlKazimi Mohammad A. , Altabbakh Hanan M.
Published: October 2015

The volitile nature of petroleum products as well as the integral convolution of the process urged the petroleum industry to pursue techniques to recognize, assess and encompass possible hazards. Together, both government agencies and non-profitable professional societies guide industry leaders with best- recommended practices. Hence, they aim at improving operations mamanement and ensure a safe working environment with processing facilties.

Regretably, accidents due to both human errors and electromechanical failures still happen and result in numerous consequences. As a result, critics have raised concerns about the petroleum industry's safety and risk mitigation credentials and question its ability to prevent major accidents. Therefor, and in to establish a rigid safety culture, the gap between both the academia and the industry need to bridged to enhance the knowledge base of safety in the petroleum industry.

The purpose of this paper to defines the establishment of "HSE Risk mamangement in the petroleum industry" course in the Petroleum Engineering program at Missouri University of Science and Technology. Not only it is designed to cover the technical aspects of HSE in the petroleum industry, but it also enhances the overlooked soft skills, ethical responsibilities, and creating safety culture.
First Application of Plasma Technology in KOC to Improve Well's Productivity
Authors: Chellappan Suresh Kumar , Al Enezi Fatma , Marafie Hussam A. , Bibi Amro H. , Eremenko Vasiliy B.
Published: October 2015

Stimulation is a well-practiced technology in oil industry to improve productivity or injectivity of a well. Plasma Pulse Technology (PPT) is a special kind of stimulation technique where oil production enhancement occurs without formation damage and without using chemical agents. PPT is based on scientific research in the areas of Geology, petro-physics, blasting theory, acoustic, wave theory and resonance theory.

Well RA-000A was identified for plasma application mainly to stimulate the very tight layer SID2 which otherwise difficult to produce through conventional perforation and to have positive production impact on nearby well RA-000B. Before application of this new technology, three intervals were perforated with last production rate @ 196 bopd with 90% water cut and closed for pressure. PNC log (sigma log)was recorded which shows that out of three perforated interval, the bottom COAL2_UCH layer having very high water saturation, the top of COAL2_UCH is having little water saturation and COAL1 LCH is almost dry. The porosity and permeability of the bottom layer of COAL2 UCH is very good whereas COAL1 LCH is having moderate rock quality. It was decided to isolate COAL 2 UCH due to very high water saturation. Also, decided to add SID layer which is very tight with low porosity and permeability

Nodal analysis was carried out to estimate the production potential after isolating the water producing layer and adding SID layer. The prosper model estimated that the selected interval will produce @ 800 to 1000 blpd with the PI of 1 to 1.5 bbl/day/psi.

After successfully executing PPT for the first time in KOC, the Production GOR test conducted after a month showed stabilized production rate of 1279 blpd, 363 bopd with a PI of 2.25 bbl/day/psi, which is two times more than the earlier PI. The liquid production is above the model predicted and achieved an incremental oil gain of 167 bopd due to plama pulse technology, ie an increase of 85% from the initial oil production rate. In addition to this, immediately after plasma application, observed 81 psi increase in pump intake pressure of the nearby well RA-000B which is 400m away from this well. It is planned to carry out plasma pulse stimulation technique in more candidates including Rigless application.
Compaction Assessment and Evaluation of Liquefaction Potential of Offshore Artificial Island Based On ‘SPT’ and ‘CPT’ Data
Authors: Konni Ganapathi Rao
Published: October 2015

In Oil and Gas industry, offshore platforms are very common in most of the regions. But, despite the fact that there may be risk of liquefaction, it is also seen that some projects demand the requirement of construction of offshore artificial islands to set up all the required facilities of the Oil and Gas plant. Therefore, in this study, a live project having offshore artificial island, about 84km offshore, has been taken and an attempt has been made to assess compaction levels achieved for offshore artificial islands. Subsequently, liquefaction potential has been evaluated based on both SPT, N and CPT data. Eventually, studied the reliability of the data for the liquefaction assessment.

The findings from this study revealed that: 1) Stringent compaction acceptance criteria shall be de-veloped based on the predefined factor of safety against liquefaction and make sure that the compaction works are in compliance to the criteria; 2) Liquefaction analysis based on the CPT data is reliable as the CPT data gives continuous profiles and represents the actual site conditions, compare to that from the SPT.

It is recommended that special care shall be taken while executing compaction works on such artifi-cial islands so as to avoid any risk of liquefaction.
Utilizing Composite Pipe Wrap Technologies to Restore Corroded Pipework to Operating Compliance
Authors: Oharriz Osmay , Bateman Colin
Published: October 2015

This paper endeavours to demystify, simplify and explain the reality of designing and applying compliant composite pipe repairs by presenting application case histories and field experience. The paper discusses the background in the development and the challenge faced by operators in applying the ISO standard to damaged pipework in the field and reviews the options for the pipeline engineer to overcome these difficulties through additional composite repair technologies.

Composite pipe repair technology has been applied in the offshore oil and gas industry for many decades, the introduction of the ISO TS 24817 standard in 2006 offered pipeline engineers the possibility to prescribe pipe repairs using composite wrap systems compliant to the requirements of the ISO standard. The engineered composite repairs, qualified, designed and installed in accordance with ISO TS 24817, provide both external corrosion protection and structural strength to the pipework/pipeline.

The paper will present the data by; discussing common misconceptions regarding composite pipe repairs and offering solutions to overcome the challenges on-site to meet the requirement for the application of compliant systems. Investigating the range and type of defects that are encountered, both through internal and external corrosive attack and reviewing the possible repair methodologies in cases where, due to the severe metal loss that has occurred and the degradation process, without additional repair techniques a compliant system could not be applied. In addition, commenting on different pipe geometries and configurations and their suitability for composite repairs.

Further comment/discussion on the use of composite wrap systems for structural repairs on equipment other than pressure vessels will also be included.
Integrated Solution to Mitigate and Prevent Black Powder Phenomena in West Kuwait Operation Facilities
Authors: Al-Qabandi Salman , Khuraibut Yousef , Al-Inzi Mohammed , Al-Dashti Adnan , Al-Nabhan Talal , Al-Enzi Ahmed , Jamsheer Abdullah , Kumar Pardeep , Thirumaran A.. , Srinivasan B.. , Al-Ghareeb Tahani
Published: October 2015

Black Powder has identified as a significant problem in all areas of hydrocarbon production facilities and transit or export lines. The phrase ‘Black Powder’ in the oil industry used to describe a contaminant found from wellhead, Gathering Centers and gas export lines. The constituents of black powder are known to adversely affect the efficiency, integrity and reliability of oil and gas production, refining and transportation. Its combines of corrosion material such as Iron sulfide, Iron oxide, Wax, Asphaltene, silt and sands. Its vary from one location to another within the process of the oil and gas production. Its presence in all areas of upstream, midstream and downstream oil and gas production. It's affecting the flow assurance and quality of performance of the facilities from compressors, vessels, tanks, sensors and pipelines and finally impacting the refinery efficiency. Its major problem start to be present recently in oil industry which many different operators have different misunderstanding to overcome these phenomena of the black powder. The paper will be to look at best strategy and solution success to mitigate the problem of the black powder in Kuwait Oil Company from west Kuwait operation facilities to Refinery. It will highlight also roots cause, Impact and prevention plan. It will show how it help reduce gas flaring, minimization facility shutdown, reduce Flowlines leaks, and optimize chemicals consumption in operation facilities which lead to cost optimization.
Response of CO2 Diffusion to Macro- and Microporosity in Carbonate Reservoirs
Authors: Yibing Yu , Moh'd M Amro
Published: October 2015

Carbonate reservoirs are known for complexity to oil recovery industry, one reason is the dual-porosity pore system. In macroporosity regions where pores are mostly effective for fluid flow and therefore viscous flow will play a role in oil extraction, while in microporosity regions contribution of pores to permeability is very limited and results in a large amount of residual oil entrapment. The purpose of this paper is to investigate the response characteristics of diffusion to porosity (include percent fraction and pore size ratio of macro- and microporosity) and permeability. Then with the help of permeability to evaluate the efficiency of CO2 diffusion for oil extraction from different porosity composition core plugs.

In order to achieve this objective, we use integrated carbonate core samples by pore structure characterization to study the feasibility of diffusion macro- and micropore regions. First, SEM and MICP experiments were introduced to characterize the bimodal pore systems, these results were combined with permeability measurement values as basic parameters for evaluation. Then the response characteristics of CO2 diffusion to macro- and microporosity will be described by the performance of CO2 injection for oil recovery with dual porosity carbonates.

With the result the first observation was the dual effect of macroporosity that it lowers the resistance for fluid flow and meanwhile reduces the exposure duration for CO2 to diffuse into the microporsoity regions. Furthermore, percent fraction, tortuosity and ratio of pore size between macro- and microporosity are critical parameters for CO2 diffusion. Also with different dual porosity component core plugs, various ultimate oil recoveries were acquired and all recovery curves were divided into two different parts that contributed by viscous flow and diffusion respectively. Through comparison the different diffusion performance in various dual porosity core plugs, response characteristics of CO2 diffusion to macro- and microporosity were finally concluded.

Acquire the knowledge of CO2 diffusion response characteristics to macro- and microporosity makes oil extraction from microporosity regions which have limited contribution to permeability possible. It shows an optimistic prospect of oil recovery by diffusion mechanism which ever been neglected and provides one more option for EOR method design in low permeable reservoirs. In addition, suggestion will be presented to extract oil effectively using CO2 injection in case of high percent fraction of microporosity reservoirs.
Improving Drilling Performance in North Kuwait by Implementing DEO Process
Authors: Armenta Miguel , Hii King-Kai , Hazarika Raju , Al-Foudari Saud Jumah , Al-Mohailan Mohannad , Debroy Amalendu
Published: October 2015

Drilling in North Kuwait presents significant challenges due to the hard rock in the overburden that needs to be drilled in large hole sizes en route to the targeted deep Jurassic reservoirs. A project was taken up in order to improve the drilling performance (especially Rate of Penetration, ROP) thought the hard layers located in three upper sections of the wells (28,″ 22″ and 16″) by implementing the "Drilling Efficiency Optimization" (DEO) methodology. DEO is an overall process to improve drilling performance by increasing ROP and bit footage through the utilization of efficient drilling practices throughout the planning, execution, and post-drilling phases.

This paper describes the strategies, practices and "Driller Roadmaps" that were developed to improve ROP and drilled footage on the three sections of interest. The drilling parameters and results from three trials implementing the proposed improvements are also included. Field data demonstrates that by optimizing BHA (Bottom-Hole Assembly) design, bit hydraulics and drilling parameters through DEO process, the ROP was improved by over 70% on average in the three hole sections in which the trials were conducted. Also, due to the ROP improvement and longer bit run durations, a total of 17 rig days was saved. One bit established a new record for the longest 22″ TCI bit run ever achieved in North Kuwait (total footage: 2883 ft). Furthermore, the entire 16″ section was drilled using only two PDC bits, for the first time ever.

The paper also provides recommendations on the next steps in DEO implementation to further improve drilling performance in North Kuwait wells. The insights provided in this paper will assist KOC in their endeavours to improve the overall drilling performance in their operations, especially drilling hard rock. The lessons learned have led to best practices being developed for the North Kuwait wells and serve as a valuable benchmark for projects located in the vicinity.
Facies Analysis and Permeability Estimation In Late Cretaceous Giant Carbonate Reservoir Using LWD Technology, A Case Study in Sabriyah Field, North Kuwait
Authors: Ibrahim H.. , Elsherif A.. , Krafft J..
Published: October 2015

Sabriya Mauddud original development plan was based on an inverted 9 spot pattern to produce oil from multi carbonate reservoir layers. Recently, Kuwait Oil Company (KOC) implemented a paradigm shift to an intensive campaign for drilling horizontal wells in the Mauddud Formation in North Kuwait. The lateral section extended for a long interval penetrating different facies of the Maudud carbonate reservoir. The need for advanced formation evaluation was highlighted as critical where the complex pore structure will play a big role in fluid mobility. Formation mobility in carbonate reservoirs has been always a challenge in any formation evaluation. The Sabriya Mauddud Formation is a ramp system, ranging from shallow restricted and barrier shoal / rudist buildup to outer ramp sedimentation. Mauddud carbonate is divided into two parts, a lower (Maj-MaG/F), belongs to outer to middle ramp dominated with intermittent influxes of Burgan delta shoreface sandstone sediments. The upper Mauddud (MaF to MaA) is inner ramp, barrier shoal / rudist build up and shallow restricted Packstone / Grainstone facies. The best reservoir quality is in the inner / middle ramp and barrier shoal / rudist build-up facies of MaE, MaD, MaC and MaB. The current strategy in Mauddud development plans is to produce high (MaB/MaC) and inject low (MaE/MaD).

The LWD resistivity was used in this field to measure resistivity (Laterolog type) to calculate water saturation. In addition, due to the fact that LWD tools measure while rotating, several resistivity images with different depths of investigation were also available in real time and recorded mode.

In this case, the LWD resistivity imaging was used to study azimuthal formation porosity distribution in order to quantify the different porosity portions (Primary / Secondary). Following that, an empirical equation was used to determine formation permeability profile. This qualitative profile is calibrated to the formation pressure / mobility with high vertical resolution to enhance permeability calculations compared to derived permeability from standard open-hole logs.

Facies determination were obtained based on porosity spectrum, amount of secondary porosity combined with relevant logging results using neural network technique. This is significant to optimize well placement in the best reservoir rock types (grainstones, rudist build up and packstones). This has been proved as successful technique for horizontal well ICD completion compartmentalization design.
Tandem ESP-Packer Dumpflood Completion Application in North Kuwait Field - A Successful Alternative to Conventional Encapsulated ESP systems - Case Study
Authors: Al-Hajeri Nasser , Anthony Elred
Published: October 2015

Dumpflooding from a strong Aquifer to support pressure to another depletion-drive reservoir is not new to the oil industry, neither to the region. In cases where the natural Aquifer pressure is insufficient to deliver adequate volumes to meet pressure support requirements, or the Injjectivity of the target reservoir is relatively low, artificial lift is required. This was the case in the North Kuwait Asset where Injectivity was poor owing to the relatively low natural fracture density of the Carbonate reservoir being flooded.

Since the conventional encapsulated (POD) systems required one (1) seal-bore packer, one (1) encapsulated ESP system, and one (1) ESP-packer, it was decided to test an alternate and simpler system that required only two (2) ESP packers that would achieve the same result of the POD system.

Deployment of this new tandem-ESP-packer system proved less complex and required less rig time than the encapsulated ESP system. Both packers were set simultaneously in one operation with the ESP function test to surface-pit giving excellent results. After opening the SSD's, the ESP operating parameters, measured at surface, indicated optimum pump performance at expected injection rates.

The Tandem-ESP-Packer Dumpflood completion system provides fewer sealing interfaces than the conventional encapsulated ESP system, and therefore fewer opportunities for leaks. Additionally, it affords a very simple one-trip system for less complex deployment, and retrieval, when necessary. This alternate system also provides easily-deployed, immediate pressure support in areas of the reservoir/field while awaiting the installation and commissioning of major surface Injection facilities.
Energy Conservation and Technical Innovation in Process Industry
Authors: Sabapathi Kanagasabai Rathina , Rajagopalan Karthik
Published: October 2015

It is important to optimize energy conservation measures in new projects in process industry. Integration of new plant with existing infrastructure is the key in energy conservation measures. New technologies like Cogeneration and Kalina Technologies are the most suitable technologies to be considered in design phase for energy optimization.

KNPC has recently commissioned a new gas plant LPG Train-4. Various energy conservation ideas are commissioned during start-up as listed below. Gas Turbine Inlet Air CoolingLow Temperature Energy ConversionCommissioning of Waste Heat Boilers to extract heat from Gas Turbine exhaust gas and using the steam as heating medium in column reboilers to achieve enhanced thermal efficiencyRecovery of heat from Spent Hot Regeneration Gas in the Regeneration systemCommissioning of control system to operate air fin-fans based on temperatureCommissioning of Debutaniser side reboilers to extract heat from Compressor discharge gas and effectively saving steam consumptionCooling Feed gas compressor discharge using Demethaniser bottom fluidVSD Motor applicationBoiler Feed water Preheat

These technical innovations are implemented in LPG Train-4 to achieve energy conservation.
Successful Proactive Geo-steering in Clastic Reservoir of Greater Burgan Field
Authors: Bahman Hussasin Ali , Hajeyya Abdullah Khalid , Al-Zankawi Omran , Mukherjee Pradip Kumar , Al-Sabea Salem Hamad , Mohammed Ali Farida
Published: October 2015

Geo-steering is a very critical part of today's field development economics, our production targets are getting more complex, thinner oil columns, which need more complex geo-steering, continual improvement needed in People, technology and processes. Drilling a well at an angle other than vertical can obtain more information by hitting the production targets and stimulate reservoirs in ways that cannot be achieved with a simple vertical well which became a valuable ability in oil business. To augment this aspect Kuwait Oil Company has established Geo-steering Center (Fig-1) which has become the hub for decision making while the well is getting drilled for landing at top of reservoir or lateral is being drilled (Fig-2).

The establishment of Geo-steering control Room in FD (S&EK) is an outcome because of constant supervision and direct guidance by manager of Field Development South and East Kuwait, which added a new dimension to drilling the modern horizontal wells in the Greater Burgan Field. The team of Geologists of FD (S&EK) in this collaboration center ensures that horizontal wells are steered correctly and safely to their final targets.

The Geo-steering center can be operated 24 hours a day if require. Each geologist may be responsible for as many as 3 wells in different fields (BG, MG & AH) and different reservoirs. Like driving, geo-steering requires constant attention and dedication all the time. The center recently moved into a new and expanded facility that is equipped with the latest in visualization, communication and computer technology in order to properly place and geologically navigate us with many complex horizontal wells path in Greater Burgan field. Geo-steering horizontal wells can be done remotely from the center, with data coming into the center from more than one well at any given time. For every well, Logging-While-Drilling (LWD) sensors near the drill bit send information about the Lithology and directional survey of the well to the control unit at the rig from where data is then transmitted by satellite to the geo-steering center. The team developed software instantly can load the data so geologists can see on their workstations the LWD and trajectory data to determine where the drill bit is in relation to the drilling plan and the reservoir target.
InSar Monitoring In Heavy Oil Operations
Authors: Del Conte S.. , Cespa S.. , Rucci A.. , Ferretti A..
Published: October 2015

SAR Interfeometry (InSAR) provides high precision ground displacement measurements remotely, using Synthetic Aperture Radar (SAR) images acquired from satellites.

Thanks to its effective provision of extensive information over wide areas with high acquisition frequency, InSAR monitoring is used routinely in the management of numbers of Enhanced Oil Recovery (EOR) projects. These include heavy oil Cyclic Steam Stimulation (CSS), Steam Flooding (SF) and Steam Assisted Gravity Drainage (SAGD) in Alberta and California.

Steam injection recovery is generally operated in shallow reservoirs with low caprock thickness, where measuring the surface effects of pressure variations at depth is extremely useful to assess steam chest expansion and enhance safety. InSAR monitoring provides low-cost effective measurements over large areas and is capable of highlighting zones of excessive pressure or subsidence, as well as to control the integrity and safety of operations and infrastructures.

This paper presents an overview of InSAR technologies and their recent enhancements. Some examples of InSAR application in EOR heavy oil projects are reported in order to highlight the advantages offered by these monitoring techniques in reservoir management and recovery optimization.
Discrete Fracture Network Models in Support of Drilling Activities in North Kuwait Carbonate Reservoirs
Authors: Richard P.. , Pattnaik C.. , Al Ajmi N.. , Kidambi V.. , Narhari R.. , LeVarlet X.. , Guit F.. , Dashti Q..
Published: October 2015

The North Kuwait Carbonate (NKJG) reservoirs are currently under development by KOC (Kuwait Oil Company). The appraisal and development of the NKJG offer challenges such as lateral variations in reservoir quality, tight to very tight reservoirs and natural fracturing to a varying degree spatially. The presence of open, connected fractures is one of the key elements to achieve a successful development. Also, the presence of fracture corridors increase the risk associated with drilling. Numerous fracture modelling studies have been supporting both appraisal and development strategies of the fields. This paper illustrates how small scale detailed DFN (Discrete Fracture Network) can support the planning and drilling activities of future appraisal wells. A series of detailed DFN models has been built around existing wells. The DFN models are based on a thorough structural understanding, detailed fracture characterization using bore-hole image (BHI) and core data around the wells of interests. In addition to the fracture characterization work, mechanical stratigraphy has been elaborated using E-facies and geomechanical logs. Fracture connectivity analysis has been carried out to calibrate the DFNs to the static and dynamic well data. Scenarios of DFN models can now be used to communicate with drilling in order to illustrate the potential fracture corridors distribution in the sub-surface.
Paper Innovative Technology to De-sulfate Sea Water or Brine for the KOC Northern Kuwait Oil Fields
Authors: Al-Maheimid Imad Ahmed , Al-Jasmi Ahmad Khaled , Al-Azmi Abdulla , Al-Hashemi Ahmed Abdulnabi
Published: October 2015

Sea water contains sulfate and formation water contains barium and strontium, if the sea water injected in oil fields reservoirs then the result is the potential for significant barium and strontium sulfate scaling and deposit & possible of reservoir souring due to SRB, s activity.

Scale deposition is a common problem in sea water injection systems, the type and severity of scaling varying between fields.

Sulfate scale formation is one of the most critical problems encountered in oil and gas industries daily activity and operations, the only effective way to avoid sulfate scale is to prevent it from forming.

To prevent barium /strontium sulfate from forming and minimizing the potential of scale formation and associated well work over and squeeze treatment costs, Sulfate most therefore be selectively removed from sea water before being subjected to injection.

A pilot plant CPP-NF (Compressed Phase Precipitation & Nano Filtration) testing was thus conducted to primarily and sufficiently deplete sulfate from sea water before being injected.

The main objectives of the pilot plant is to study and evaluate the feasibility and cost-effective of CPP-NF technology for de-sulfation of sea water and/or MSF brine in Subiya Sea Water Treatment Plant SWTP, the foundation of the selected technology rests on how KOC can : 1) - increase the value and quality of the injected sea water, and 2)- implement the technology in such a way that the improved sea water quality would not cost more than the current situation and serve KOC long term goals.

The pilot testing was very successful and the removal of sulfate was consistently in the range of 98–99%, furthermore, the pilot testing also revealed that the issue of high TSS (Total Suspended Solids) within the facility can be resolved at no additional cost.
Kuwait Digital Integrated Field - Enabling Virtualization technology for a step Change
Authors: Saleem H.. , Al-Shammari R.. , Al-Mai N.. , Robert H.. , Saxena M.. , Joy S.. , Rao P.. , Ismail M..
Published: October 2015

KwIDF is a complex cross-domain solution consisting of a fully integrated infrastructure which supports field instrumentation, automated workflows and ergonomically designed collaboration solution. This paper describes virtualization technology and associated improvements in processes that will improve the Digital Oil Feld infrastructure resources and allow KOC's Corporate IT Group with tools to achieve more flexibility in delivering business critical data that translates into decision-ready information and collaborative support.

After three years of operation, data volumes are increasing rapidly with multiple workflows driven by multiple applications and the current infrastructure is not adequate to provide optimum performance. Added to this, complex workflows are planned for the next stage of development which will demand performance that the current system will not be able to deliver.

Though there are dedicated servers for each application, it is difficult to manage the application servers and storage. Therefore, it is essential to build a robust infrastructure for the current and future environments which will only become more complex with the onset of advanced workflows and exponential increase in the volume of data.

This paper describes the virtualization solution for Kuwait Digital Integrated Field infrastructure which will improve the utilization of resources, enable high availability and provide better disaster recovery solution. The solution will include the SCADA industrial network and the corporate user network which will allow KOC to achieve measurable business benefits such as reduction in the cost of IT Infrastructure while improving performance and reliability
KOC Flaring Success Story
Authors: Al-Zuwayer Hamad R. , Singhal Vineet , Al-Sughayer Nasser Y.
Published: October 2015

Kuwait Oil Company (KOC), an upstream subsidiary of Kuwait Petroleum Corporation (KPC), is in the business of exploration & exploitation of hydrocarbons in the state of Kuwait. While it ranks amongst the major oil companies of the world by virtue of its oil reserves & crude oil production, due to an inherently low GOR of its flagship oil fields, Kuwait has not been very gas-rich and has been compelled to practically utilize all of its produced gas in order to meet its needs. The gas utilization presently ranges in excess of 98.8% which translates to a flaring level of a little above 1% of the produced gas. The plan is to reduce flaring further down to < 1% soon by increasing the gas utilization to over 99%. Managing sour rich gas is KOC's biggest challenge since its utilization (or flaring) is largely dependent upon availability of gas sweetening and/or sulfur recovery units. Increasing LP:HP ratio has added another dimension to the challenges being faced by KOC. This paper discusses KOC's endeavours & strides in meeting the gas flare reduction challenge.
Reservoir Characterization by 3D Modelling of Water Encroachment Using Time Lapse Pulsed Neutron Logs in a Heterogeneous Shalysand Reservoir of Greater Burgan Field
Authors: Madhavan Sethu , Al-Hashash Haya , Al-Arbash Abdulla
Published: October 2015

Wara reservoir of Greater Burgan field is a heterogeneous shaly sand reservoir deposited in fluvio-deltaic environment. Modeling the changes in hydrocarbon saturation and water encroachment in Wara reservoir has been a great challenge due to a combination of factors like heterogeneity, multiple Oil Water Contacts and multiple Oil Gas Contacts etc. Understanding the water encroachment and monitoring zones of water breakthrough is a key for effective water flooding reservoir management. Pulsed neutron capture (PNC) logs are commonly used for formation evaluation behind casing and to assess time-lapse variations of hydrocarbon saturations. Systematic time-lapse PNC logging can give a detailed description of hydrocarbon saturation changes in response to injection and production operations during water flooding. This paper addresses the workflow that has been utilized to create a 3D static model of Water encroachment using flags that characterize the swept and partially swept zones in the reservoir created from Sigma curves of Time lapse PNC logs along with synthetic sigma curves from the open whole logs acquired at the time of drilling the well. The remaining oil in place volume which was estimated from the sweep model was consistent with the volumetric of the simulation model and with the remaining oil in place calculated from the production data. Volumes of different vintages are created with time lapse PNC logs. The difference between these volumes can be used to understand the complex water encroachment in the reservoir due to multiple oil water contacts and also it can be used as a source to calibrate the 4D seismic data acquisition model. Connected volumes of the swept and partially swept zones computed from the model were utilized to visualize the swept zones.