bluuebunny/crossref_metadata_2025 huggingface dataset:
Water Analysis - A Key Tool for Reservoir Monitoring Under Cyclic Steam Stimulation
Authors: Jain Anil Kumar , Ahmed Khalid , Ortiz-volcan Jose L. , Al-Khamees Waleed
Published: October 2015

During the process of Cyclic Steam Stimulation (CSS) variations in reservoir pressure and temperature occur changing the solubility of reservoir rock minerals in the formation water and therefore during production phase, produced water brings valuable information about dynamic characteristics of reservoir rock and fluid. Its analysis may provide an invaluable means for monitoring the reservoir. This paper describes the process of water analysis where results are interpreted on the basis of the principle that the solubility of minerals varies with change in pressure and temperature. This also shows the importance of water analysis as a key tool for reservoir monitoring in fields undergoing cyclic steam stimulation.

Water analysis is also used to optimize impact of produced water on Capex and Opex of oil production as water is required to be handled and disposed without impacting the environment, and is applied as troubleshooting tool to identify well problems and to validate log interpretations.

Field examples illustrate application of water analysis in i) mineralogical changes that takes place during CCS operation for reservoir monitoring and impact of steam on clays, ii) determining compatibility of injected steam with the formation water and compatibility of effluent with the formation water of disposal well, iii) surface facility design and water treatment before steam generation, iv) reservoir description and computing fluid saturation using resistivity of formation water and v) troubleshooting well problems, e.g. unanticipated water production because of channeling behind the casing and communication between the layers.

Paper discusses the importance of water analysis at each stage of CSS operation and its application in reservoir monitoring and describes field experience with water analysis in the surveillance of a CSS project.
Evaluation of Surge Protection Systems to Enhance Bunker Loading Rates to Ships
Authors: Mathew Benny
Published: October 2015

Offshore Oil export, being a batch process, is required to be at the highest loading rate possible to lift off the continuously produced oil and also to shorten the loading period of ships, so as to improve the time to market. But at the same time, it needs to be managed in the safest manner, as any operational error or a bad weather could cause a big oil spillage and pollute the marine environment significantly. This calls for a bigger offshore infrastructure, with large size and lengthy submarine pipelines all the way to the deep draft area of the sea to enable bigger ship to berth and a higher pumping rate with fail safe control system.

KOC started offshore crude oil export in year 1969, with the commissioning of Sea Island terminal located 10 miles offshore. It had a 48″ dia. Crude oil Submarine line and a 20″ bunker submarine line. The control system for emergency shutdown was provided with a surge relief system and a relief collection vessel at the sea Island platform. After 10 years, in 1979, a new single point mooring (SPM) terminal was added with surge relief collection vessels and the submarine lines were extended from Sea Island further 3KMs to connect with SPM. In year 1996, two new single buoy moorings (SBMs) were built and the same old submarine line was further extended 3 KMs each to connect with both SBMs. In year 2008, the complete offshore system was re-built with new offshore infrastructure as detailed under.

The present new offshore infrastructure consists of four (4) nos. of single buoy moorings (SBMs) of catering anchor leg mooring (CALM) type, each with a dedicated 56" dia. submarine pipeline of length over 20KMs, so as to cater the biggest range of oil tankers in the world. The crude oil loading rate could be over 100,000 bbls/hr simultaneously in each of the four CALM buoys. For bunker service to the crude oil ships, a bunker loading system consisting 20″ & 24″ submarine pipelines are also in place, to meet a maximum loading rate of 1000 Mt/hr for fueling the ship. The offshore loading terminal of SBM type, is a floating buoy without any permanent structure and is remotely controlled from an on-shore control room. The ship is moored to the buoy on a single point, so that it could move- weathervane - around the terminal. In the event of ship moving away from the terminal due to very bad weather or any other reasons, the crude/ bunker loading to the ship would be stopped automatically by a breakaway mechanism on the hoses. This would result in high surge pressure in the loading system and the weakest link, which is the loading hose, would be protected by isolating the same from the upstream by sudden automatic closing subsea valve (PLEM) together with emergency shutting of on-shore export pump.
Heavy Crude Oil Sampling and Assay For Refinery Capacity Planning: Design, Plan and Execution In A Supergiant Green Field
Authors: Ortiz-Volcan J. L. , Ghouti R.. , Al-Naqi A. M. , Jain A. K.
Published: October 2015

Assessing heavy oil composition of a green field, with an accepted level of uncertainty so it can be used for refinery capacity planning is a critical challenge. Knowledge of heavy crude oil properties is vital to understand potential adverse impact on process performance and total costs of the whole value chain, downstream (corrosion, catalyst deactivation, fouling and pumping) and upstream (corrosion, fouling, obstruction, producibility, lifting, pumping and transportation).

The usefulness of heavy oil properties is highly dependent upon how samples are representing the bulk of hydrocarbon resources that will be developed and the reliability of the sampling procedure which becomes even more challenging when performed in a geologically complex, multilayered, supergiant green field with wide variations of fluid properties vertically and aerially.

In this paper we present a field case with the methodology used to design, plan and execute a heavy oil sampling and essay for refinery capacity planning and the lessons learned, in an area of the field representing the first phase of development, in a supergiant heavy oil green field located in north of Kuwait.

This heavy oil sampling and essay was planned and executed under high levels of uncertainty, using previous crude assays, PVT data from appraisal and thermal pilot wells and reservoir static and dynamic model. Extensive statistical analysis was applied to understand and map uncertainties related to sampling, completeness and representativeness of laboratory tests vs. accepted international standards. The methodology was applied by a multidisciplinary project team involving specialists from upstream and downstream who performed the work using project management tools to design and implement the execution of sampling in the field. The project took near one year to complete and results are now used for refinery capacity planning at short and midterm. Lessons learned were documented so the future sampling and assays can be improved as data from more wells is going to be available during execution of development phase.
Improving The Electrical Submersible Pumps Operational Time By 50% Using The Six-sigma Procedures
Authors: Ahmad M.. , AL-Refai S. I.
Published: October 2015

Electrical submersible pumps (ESP's) downtime is one of the most significant concerns that affect the oil production sustainability. Various defects as electrical trips, mechanical issues, under or over load trips and manual shut off are keeping the pumps off operation that would suspend the well productivity. The downtime of ESP's generized by generators globaly is exceeding an average of total 2 days per well from a population of 400 pumps. This is directly reducing the total daily production. The objective is to reduce the operational downtime by 50% after allocating the most marking defects to increase the pump's spinning time and maintain the wells’ production.

Statistical study using the Six-sigma procedures is employed to accomplish the downtime reduction. The problem is defined as reducing the ESP's downtime by 50%. The spinning hours are measured in daily bases from 400 wells and the downtime is calculated. Moreover, each defect is categorized to a main reason branch. The branches are mainly consisting the reservoir characterizations and the formation type. In addition to that, the data is analyzed using the ANOVA analysis road map and the hypothesis testing procedures.

The analysis showing that most of the defects are electrical ones, that is because of using diesel generators to energize the pumps. An improving process is encountered to overcome this problem by substituting the generators with the government electricity. In the other hand, high amount of defects are considered as reservoir effects while the pumps are tripping because of under or over load. The main reason behind this kind of pumps’ tripping is the pump design and the high water cut of the well. An appropriate pump design procedures are organized to reduce this kind of defects. Also, optimization practices are developed to set the right pump situation that would enhance the well productivity and minimize the operational downtime.

In order to control the ESP's operation, several monitoring methods and applications are used for taking actions toward any abnormal pump behavior as V-Monitor, SCADA and daily ESP reports.
KOC's Effort Towards Better Fiscal Metering
Authors: Alanzi Mishaal
Published: October 2015

As part of the continual improvement and expansion of Kuwait Oil Company’s (KOC) infrastructure, the company is currently executing mega fuel gas and liquid fuel projects for the ever increasing demand of energy consumption. The major overhaul of KOC’s existing network is being improved and expanded by three mega projects. Two of which are identical and handle the demands of Minsitry of Electricity & Water (MEW) North & South Kuwait power stations. Whereas, the 3rd project, which is called the Telemetry Project, is being implemented to provide telemetry, automation, leak detection system and fiscal metering for the whole network. Furthermore, this telemetry project has an independent SCADA system to meter, monitor and control large diameter cross-country pipelines remotely from ultra-modern control rooms; Consumers Network Management Center (CNMC) and Secondary Network Management Center (SNMC). The total gas delivered under these projects exceeds four BSCFD and includes custody-transfer class metering skids and associated systems. Custody-transfer measurement is of great importance within KOC’s downstream business in order to meet Kuwait Petroleum Corporation’s clients, large and small users. This technical paper shows the positive impacts and huge contributions these major projects made. Another focus is on the different philosophies used in the metering skids and various applications of flow meters in the projects. Dew Point Depression Units (DPDU) is the first facility ever built in Kuwait and such decision shows KOC’s emphasis in opting for technology beyond traditional use. Furthermore, a comparison of the gas and liquid flow-metering skids under the three projects gives us a very fruitful analysis in terms of selecting the best features and avoiding the shortcomings of all three designs. In addition, the analysis compares the flow-spitting or control switching, proving systems, calibration procedures and flow-computation besides other features. In conclusion, the state-of-the-art technologies of flow metering solutions made huge and significant improvements as well as reached new levels of reliable flow measurement. Whereas, in the past, a certain and limited number of applications were available and used which resulted in poor flow measurement and higher uncertainty/error. This particular comparison, between the old and new consumers networks, emphasizes KOC’s position in achieving and obtaining innovative flow measurement solutions.
Implementation Of Non-man Entry Technology- An Automated Technology for De-sludging & Cleaning of Tanks
Authors: Al-Dousary Sharian , Dharan Ganga Prasad
Published: October 2015

De-sludging is the process of removal of sludge from the tank and dispose it in an environmentally friendly manner. It is required to be carried out when the sludge level increases in the tank and affects the operation of the tank or to carry out the maintenance activities of the tank.

Generally De-sludging is carried out by man entry method in which personnel enters the tank wearing all the required PPE’s and remove the sludge using various tools like Hydro Dozer, Shovels, Scrappers and Movable containers. The removed sludge is transported to the Crude Recovery Unit by vacuum tankers for further treatment.

Manual method of de-sludging carries following difficulties:

Working environment inside the tank is unsafe/dark and Workers are exposed to hazardous gases like H2S, Hydrocarbon, etc. Negative Environmental Impact during handling of sludge The activities take long period and requires high manpower(15-30 personnel) Sludge with very high solid content cannot be treated through crude recovery system.

Non-man entry technology is the method by which the sludge from the tank is taken out without any personnel entering the tank. The treatment of the sludge is carried out through an automated process inside the bund wall of the tank.

This process utilizes nozzles fixed on tank roof (by cold cutting) to spray the oil into the tank to shear and re-liquefy the sludge in order to transfer it from the tank. The sludge taken out from the tank drain nozzle is circulated through the sludge treatment unit which consists of centrifuge and high/low speed decanters. Once the recovered oil achieves the desired quality as per the lab results, it is transferred to the adjacent designated tank. Remaining layer of oil from the tank is removed by washing with fresh water followed by washing with water mixed with detergent. Tank manholes were opened and fixed with pneumatic blowers for ventillation. Workers enter the tank based on the clearance by Company’s safety person to clear the residues and to carry out the cleaning of areas inaccessible to the cleaning nozzles.

Recently, Kuwait Oil Company successfully implemented the non-man entry in two tanks and found having following benefits.

Safe, Healthy and Environmental friendly solution with reduced emission of hydrocarbon No workers enter the tank during de-sludging & cleaning and hence reduces the exposure to various hazards Closed system, not exposed and Continuous monitoring Activity duration can be reduced up to 50% of manual method Totally automated process and hence requires less manpower (5 personnel). All types of sludges irrespective of the oil content can be treated Totally safe in explosive and dangerous areas

It is the first implementation of such technology in K-Companies that has improved the HSSE performance and added great value to the maintenance practice of the Company.
Thickness of Concrete and Steel Front Wall Claddings for Various Blast Pressure in Blast Resistant Buildings
Authors: Singh Jitendra Pratap , Roy Anindya
Published: October 2015

Blast resistant buildings consists various combinations of wall claddings and structural system. Cast-in-place concrete and corrugated steel plates are most common front wall claddings that are being used in the industry. Wall cladding is an important element of the building because this is the first barrier of the building against the blast wave. Its dynamic interaction with the blast wave depends on its geometry, material properties and blast wave parameters. While ductility and fundamental period of vibration are the primary factors which controls the resistance against blast. Wall claddings are attached to the structural system, therefore the blast reactions from the edges are being transferred to the structural system. This reaction is function of ductility and fundamental time period of wall cladding.

Construction of concrete front wall needs some flexibility in schedule of the project while corrugated steel plates require higher budgetary demand on the project. Therefore in the present paper, a parametric study being done to calculate thickness of front wall for various blast pressures, duration of blast pressure, reinforcement, span of wall for a simply supported end condition, which is the most common boundary condition in the practice. Ready to use charts are prepared to estimate the quantities in design.
A Comprehensive Surveillance Plan for Steamflood Pilots
Authors: Sanyal T.. , Al-Khamees W. K. , Bagheri M.. , Abdulraheem H.. , Al-Sane A.. , Al-Ali Yacob
Published: October 2015

The development of the vast viscous oil resources of Kuwait is considered a very important strategic goal of the country. The first phase of development plans is under implementation to meet a target production of 60 M bopd by a combination of cold flow and cyclic steam stimulation (CSS) followed by steamflood to have optimum recovery from this resource. The thermal development plan for the viscous oil resources, targeting high recovery factor from this resource, is considered to be the first EOR project in Kuwait. The thermal project starts with Cyclic Steam Stimulation followed by steamflood. To optimize the process and maximizing recovery, three pilots have been planned for evaluation of these technologies in this field. A detailed plan was developed to ensure quality surveillance information is obtained to support this pilot performance interpretation. This present paper summarizes the salient features of that surveillance plan and how the planned data can be interpreted, to obtain maximum value from the pilots.

First the impact of known reservoir uncertainty parameters was evaluated through simulation studies and field testings, to evaluate their potential to become major risk parameters for the project. A commercial uncertainty analysis software to identify risk factors was used for this study. A comprehensive surveillance plan for evaluation of the potential risk parameters in the pilots was then firmed up, based on available technologies in the industry.

The study identifies that an integrated approach is needed involving the completion plan, surveillance options and project goals to optimize learning from the pilots. A realistic surveillance plan, which caters to the different completion plans being evaluated in the pilots, was firmed up. The study also recommends frequency and resolution needed in the surveillance data, for meaningful interpretation of results.

A comprehensive surveillance plan in the pilots is considered a key success factor in EOR projects. With increasing demand for fossil fuels in future, evaluation of EOR technologies through pilots would continue to remain a desired option, to reduce project cost and risk. The risk assessment approach elaborated in this study is expected to have relevance in similar EOR projects all over the globe.
Processing Heavy Crude
Authors: AlRashoud Anwar M.
Published: October 2015

Kuwait has abundant proven reserves of oil and recent discoveries suggest that Kuwait has significant heavy oil reserves as well. Heavy Oil in Kuwait ranges from conventional (easy to produce) 16 °API in lower Fars and unconventional (difficult to produce) tight oil and Tar-Mats. Developing these reserves in an environmentally compliant and sustainable manner is a national priority. The challenge of increasing national production to 4 million barrels per day will depend in large part on our ability to develop and adapt the technologies necessary to be able to exploit these heavy oil reserves.

There are around 160 types of crude oils being produced worldwide and the price differentials between crude oils can be $15 /barrel or higher. Refiners find themselves faced with the difficult question of searching for crude blends to maximize the use of their existing assets or to choose crude blends, which will require additional capital investment but will offer opportunity to increase return on investment. As per World Oil Outlook by OPEC, a continuation of moderate light-heavy crude differentials in the medium-term is indicated, followed by a progressive widening in the long-term. The moderate differentials in the short-term stem from the existence of excess refining capacity and the lightening of the global crude slate. The long-term trend toward a widening of the differentials, with heavy sour grades especially affected, is mainly due to a return over time toward a more balanced downstream as well as a gradual shift toward a more heavy crude slate. This will be alongside continued declines in inland and especially marine residual fuels demand. In addition, the on-going trend toward sulfur reduction in transport fuels will further differentiate crude oils depending on their sulfur content. In General, an Increase in Light-Heavy differential on both crude side and product side indicates better Refining Margins leading to improved profitability.

Historically, the petroleum industry supply chain has been divided into three discrete sectors: production, transportation and refining. Typically, crude is produced and made ready for transportation by production operations, and it is transported via pipeline or ship, train or truck to more sophisticated and complex refineries. Once at the refiner, the crude oil is refined into transportation fuels and other high-value finished products. The downstream sector of the hydrocarbon industry continues to optimize processing schemes to take advantage of the lowest-cost crude oil, of which a significant portion of the "opportunity crudes" are heavy oils.

Maximizing domestic processing of Heavy/Sour crudes is a KPC 2030 Strategic Direction for KNPC. Accordingly, Al-Zour Refinery (ZOR) is planned to handle heavy crudes. However, Processing of Heavy Crude in an Oil Refinery is an opportunity as well as Challenge. In my presentation, I will highlight the same from a refining business prospective.
Excellent Stimulation Results in Deep Carbonate Reservoir in Marrat Formation in Magwa Structure in Greater Burgan Field Kuwait
Authors: Snasiri Fatemah , Abdulrazzaq Eman , Tirkey Naween , Kotecha Rohit , Gazi Naz H. , Al-Othman Mohammad , Al-Sabea Salem , Ali Farida
Published: October 2015

Marrat reservoir in Magwa field in Greater Burgan, Kuwait is a carbonate heterogeneous reservoir belonging to Lower Jurassic. Marrat is classified as a tight reservoir with an average permeability of 17md and contains light oil of 38deg API. The formation is around 2400ft thick divided in three sub layers namely Upper, Middle and Lower Marrat. Middle Marrat is the main oil reservoir which has been perforated and tested to be oil producing in almost all the 30 drilled wells. The reservoir consists of Grainstones, Packstones, Wackstones and Mudstones. Marrat was put on production in 1984 and solution gas drive is the main drive mechanism. The reservoir is naturally depleted due to limited water aquifer. The reservoir pressure declined 17% from the initial reservoir pressure within 15 years to current pressure of around 8000 PSI. Field Development Plan envisages pattern and peripheral water injection and facilities development for water injection is planned. Asphaltene flocculation at wellbore, tubular and surface facilities has been recognized as a severe problem. One of the options to avoid asphaltene problems in the reservoir, including the near wellbore region, is to maintain reservoir pressure and flowing BHPs above the asphaltene onset pressure (AOP) of ~ 6500 PSI.

Formation fluid contains around 1000 ppm of H2S and 4% CO2 which throws a corrosive environment also to tackle with. The well head equipment with present metallurgy often leaks on pressure tests and there is a plan to replace during future work over jobs. Coil Tubing Cleaning of tubular with light aromatics is a routine operation to maintain production from wells.

Increased demand of oil necessitated safely increasing oil production from Marrat reservoir. Keeping in view the challenges, a multi-disciplinary team was formulated to look into all possibilities. Focus was on Acid Fracturing Technique which had proved to be successful in the past. However with advancement in acidizing and diversion chemicals, the new system was field trialed.

This paper will discuss the process to select the wells and successful attempt of acid fracturing in two wells to tap oil from new areas.
Production Enhancement Strategy in Lower Burgan Reservoir: Greater Burgan Field, Kuwait
Authors: Naik Vinay , Jasem Mariam , Al-Enezi H. S. , Al-Matroud F.. , Haryono R.. , Behera P. K.
Published: October 2015

A comprehensive development strategy for BGSL1 reservoir of Burgan Formation, deposited in Lower Cretaceous, of Greter Burgan field, Kuwait was formulated to increase the production of the low productive heterogeneous reservoir. The BGSL1 reservoir was deposited in shore face dominated coastline with protected tidal bay. The heterogeneous nature and low Sand: Shale ratio makes development of this important reservoir difficult. After studying the production performance of BGSL1 reservoir, mainly four technical challenges are identified. These are 1) wet production, 2) low productivity index, 3) short self-flow life and frequent work over needed and 4) Complexity in terms of lower API crude, multiple oil-water contacts and heterogeneity.

Initial study for BGSL1 reservoir was started by revisiting all the wells drilled to BGSL1 reservoir. Remaining Oil distribution maps of each sub-layer were prepared which had given clear understanding of potential of this reservoir. BGSL1 reservoir remaining oil map was divided into several compartments. On the basis of volume, 24 compartments were identified as under-developed in terms of their current off-take rate to current remaining oil volume. Some of the compartments are preferred for development than other due to development opportunities for more than one reservoir.

Development of BGSL1 is highly challenging. The reservoir may require planning single dedicated completions with artificial lift. A novel approach was adopted to screen the candidates for artificial lift, which was based on highly underperforming wells, where self-flow with good rate is not possible due to high water cut and declining production. Evaluation of these ESP candidates were done with remaining oil column, bypassed oil & partially swept zone potential with rock quality, PI measurement and historical plot of liquid rate & water cut to review the well deliverability and to estimate water cut with ESP.

The technical challenges were resolved to a great deal. For reservoir complexity like multiple oil-water contacts & heterogeneity, unit wise estimation of remaining oil has helped. High viscosity oil mapping helped to isolate low API / high viscous oil. It was seen that study helped to achieve a rise of oil production and using these practices helped to reach highest production over last decade.
Selecting the Optimum Waterflood Concept and Water Quality Specifications to Maximize Production
Authors: Aristov Sergey , van den Hoek Paul
Published: October 2015

Waterflooding is the most widely used secondary recovery concept in the oil industry. Once embarked on, it becomes vital to assure the proper planning and execution of a project. There are multiple examples of things that can go wrong if the project is not properly designed, and/or if the practices and standards are not adhered to. These include loss of injectivity, out-of-zone injection, early water breakthrough, loss of reservoir containment, significant CAPEX/OPEX overruns, injector-producer shortcircuiting, reservoir souring and scaling issues etc.

Waterflooding concept and corresponding water quality is one of the overarching themes in a waterflood project. It requires an integrated multi-disciplinary approach to conclude on an optimum design and strategy. Some of the issues that need to be addressed in the first place are: –matrix of fractured regime–injectivity decline and necessary water quality specifications–fracture growth over time and its impact on sweep–risk of out-of-zone injection and loss of reservoir containment.

Realising the magnitude of these questions, Shell has developed a suite of tools to tackle these issues and help in adequate designing and optimization of waterfloods. They include: –ASCET (Actual and Simulated Coreflood Evaluation Tool). On-site coreflood tests at real-life conditions, measuring formation impairment as function of water quality.–FORDAM (FORmation DAMage) software. Estimation of injectivity decline when no ASCET tests are available.–PWRI-FRAC (Produced Water Re-Injection FRACture modelling). Quantification of fracture growth as a function of water quality and injection rate.–FRAC-IT (FRACture IT). Model the impact of fracture growth. Assess risk of out-of-zone injection and impact on sweep.

Utilising these tools helps make informed waterflood decisions, improve water management, reduce (or eliminate) water disposal, lower environmental impact, avoid unnecessary CAPEX/OPEX.
Improvement of the CHOPS Process Efficiency
Authors: Naderi Khosrow , Romaniuk Nikolas , Ozum Baki
Published: October 2015

Heavy oils with about 500 cp to 50,000 cP viscosity in unconsolidated sand reservoirs are commercially produced without heat injection, by a production method known as the Cold Heavy Oil Production with Sand (CHOPS). CHOPS reservoirs are generally about a kilometer wide and may range from 3 to 5 m thick sand blankets to 35 m thick sand channels which are between 0.5 to 5 Darcy permeability, 28 to 32% porosity, and have about 88% oil and 12% water saturations. CHOPS production is always coupled with the production of the dissolved gas, mostly CH4 and minor amounts of H2S and CO2, and sand production which causes formation of wormholes in the reservoir. Formation of wormholes in the initial phase of the reservoir life promotes oil migration and thus increases oil production; however, continued wormhole formation in long term operations reduces the oil production rate and harms the sweeping efficiency of the original oil in place, typically to less than 10%. Because of low sweeping efficiency, several Post-CHOPS process concepts have been investigated to recover the remaining oil in the reservoir.

The objective of the present study is to increase the production and sweeping efficiencies of CHOPS and Post-CHOPS processes by altering the wettability of oil and reservoir sand as well as the wettability of oil and connate water and/or water injected into the reservoir. In this study, an oil-water emulsion sample produced by CHOPS process was centrifuged to separate the oil and water phases to avoid using chemical demulsifiers. The separated oil and water phases were physically and chemically characterized and the oil-water interfacial tension was determined using pendant drop method at a temperature range between 20 to 50 oC. The effects of solvent, surfactant, and pH on oil-water interfacial tension were independently investigated by either diluting the oil with pentane as a solvent additive (5% to 15% by mass of oil dosages), emulsifying biodiesel (fatty acids methyl esters, chemical formula: CnHm-COOCH3; m<2n+2) as a surfactant additive into the water phase (0.05% to 0.3% by mass of oil dosages) and altering the pH of the water with using NaOH and HCl.

Results of these studies suggest that bitumen mobility and sweeping efficiency of CHOPS and Post-CHOPS processes could be improved by reducing the oil-water interfacial tension. The present experimental research demonstrates that oil-water interfacial tension could be reduced by either a basic or a nonionic surfactant additive. Implementation of these findings to CHOPS and Post CHOPS processes needs further understanding of the CHOPS reservoir characteristics. Laboratory test results are encouraging enough for further laboratory and field trials to increase the production and oil sweeping efficiencies of the CHOPS reservoirs.
Improve Production Allocation by Linking the Well Model to the Live Well Data in the North Kuwait Jurassic Fields
Authors: Abrar A Hajjeyah , Roshan Prakash , Omar E L , Noura Al-Mai , Mubarak D Al-Mutairi , Abdul Aziz H
Published: October 2015

The paper presents a semi-automatic workflow for the production allocation to individual wells, by linking a steady state model to the real time surveillance data in the field's area of Kuwait. The onshore fractured carbonate fields consist of six fields and produces from four different structures connected at the surface to a single processing facility. A robust production allocation process was successfully developed and implemented for the complex reservoir characterized by high pressure & high temperature (HPHT) environment, critical or near critical nature of the reservoir fluids, high concentration of H2S & CO2 and multiple zones consisting of layered shale and limestone, which can be heavily fractured.

The automation was carried out in phases. In the initial phase, the Digital Oil Field (DOF) concept was started by instrumenting existing 30 wells and building the workflows by considering the HSE, operations and engineering requirements of the asset. Phase-1 of this technology program called as Kuwait Integrated Digital Field (KwIDF) was started in 2010 and deemed complete in mid-2012, with the key focus on engineering workflows to provide model based well rate estimation as the key input to the production allocation process.

Significant improvements have been observed after the allocation process was automated when compared to the off line manual system, which was time and effort consuming and was prone to errors during data migration between different databases. The new system is scalable for the future as more wells and new facilities will come on line based on the expansion plans of the Jurassic field.
Sucker Rod Pump Design Modification to Avoid Pump Floating Phenomena in Heavy-Oil, Low API Wells to Enhance the Production Rate
Authors: Quttainah R , Mehmood F , Mesbah Hossam , Dange A , Sierra T
Published: October 2015

Producing heavy oil from shallow wells using rod pump applications requires careful design considerations especially for down hole components to achieve maximum production rate and maximize the run life. This paper highlights a successful case study of one such heavy oil sucker rod pump well, in the North Kuwait field of Kuwait Oil Company (KOC), where the rods were specially designed to penetrate through the viscous oil and address the pump floating problem to achieve uninterrupted pump operation. Conventionally, as a rule of thumb for the shallow wells, the rod design initially constituted of twenty percent sinker bars and eighty percent sucker rods. This was to add weight on the pump for stability and proper balancing. In the case of this well, with the same design philosophy employed, it was observed that the pump floated over the viscous oil. The maximum pump fillage was observed to be less than fifty percent. Eventually operational changes were made by reducing the speed and operating at maximum stroke length. However this still did not bring any improvement. Hence, specific design modifications were made in the rod string and the pump size to be able to solve the pump floating problem, achieve maximum production rate, and operate at the maximum possible efficiency. Following the design change, it was observed that the pump was now able to penetrate through the viscous crude effectively. This increased the pump fillage to 75% consistently, enhancing the production rate. It was also observed to improve the unit balancing. This well design was considered as part of the pilot in heavy oil project in north Kuwait field. Since the floating pump phenomena is expected in KOC heavy wells, this design would be employed on similar sucker rod operated wells and neighboring wells suffering from the same well conditions. It is expected that by overcoming this operational issue there will be considerable cost savings and production enhancements.
Evaluation of an Unconventional Shale Resource Play Using Advanced Spectroscopy Measurement: Case Study from Kuwait
Authors: Khan B.. , Ghneej A. Abu , Joshi G.. , Acharya M.. , Van Steene M.. , Wiryoutomo M. D. , Darous C.. , Al-Azmi M.. , Dashti Q..
Published: October 2015

An advanced neutron spectroscopy measurement combining capture and inelastic spectroscopy with state-of-the-art hardware has been used to directly determine total organic content (TOC) and to provide detailed mineralogy characterization in an organic-rich source rock in Kuwait. The advanced spectroscopy measurement provides a direct measurement of TOC, obtained from the difference between the measured total carbon and the inorganic carbon obtained from the rock mineralogy. TOC is an important component of the evaluation of an unconventional reservoir as it is a direct input into the determination of the adsorbed gas volume.

Core studies including X-ray fluorescence, dual-range infrared Fourier transform mineralogy evaluation, and coulometry for carbon were conducted to validate the measurement. The log spectroscopy results were compared with core TOC data and to core elemental and mineralogical data. Evaluation of the advanced spectroscopy tool was conducted in parallel with the previous-generation spectroscopy measurement to compare the results.

The core TOC and the direct TOC log measurements of the advanced spectroscopy tool compared well. The core-to-log elemental dry weights comparison highlighted that, compared to the previous technology, the advanced measurement provided a more accurate evaluation of several elements (including aluminum, potassium, and magnesium). The core-to-log comparison also demonstrated that the new measurement provided robust answers in a tough logging environment, with an effective correction for the carbon content of oil-base mud and for barite, despite the high barite content in the mud. A particular finding of the chemistry/mineralogy combined core analysis was that a large quantity of sulfur, larger than is typically found in unconventional reservoirs, is associated with the kerogen.

For the first time in Kuwait, the application of an advanced spectroscopy technology in a challenging carbonate environment effectively provides a detailed and accurate mineralogical description and a model-independent TOC measurement that were not previously available with conventional spectroscopy logging techniques.
A Comparative Investigation of Nano Particle Effects for Improved Oil Recovery – Experimental Work
Authors: Salem Ragab Adel M. , Hannora Ahmed E.
Published: October 2015

To maintain the production and improve the recovery of hydrocarbons, nano materials are introduced recently. Improved oil recovery (IOR) is the application of various techniques for increasing the quantity of the crude oil that can be recovered from a hydrocarbon oil field. Among these techniques are chemical injection, which has been an expensive method, and field applications have been decreased during the past two decades. Currently with the advent of nanotechnology, nanofluids have been launched as a cheap, efficient and environmentally friendly alternative to other chemicals. Nanomaterials has been created and proposed to be used for IOR. Several nano materials with various sizes and concentrations have been proposed. Among the various these nanomaterials, nano-silica, nano alumina, nano zinc, and nano iron with different sizes has been recommended.

In the present work, two different nano materials used to improve the recovery of oil experimentally. These nano materials are; nano silica, and nano alumina. The size of each nano material is varies from 80 to 87 nm. The size and shape of each particles were examined using x-ray diffraction (XRD) and field emission-scanning electron microscope (FE-SEM) while their microanalysis was performed by Energy Dispersive System (EDS). Some these materials are prepared mechanically using ball mill such as nano silica and the others are created chemically such as nano alumina.

Numerous flooding scenarios have been performed to compare between the potentials of each nanofluids used to improve the hydrocarbon recovery. A control experimental run with water flooding (WF) was performed first. The ultimate recovery factor by WF was found about 67%. Then a flooding process using each nano fluid has been conducted for three different concentrations (0.1, 0.5, and 1 wt%). The ultimate recovery factors have been measured for all of these nano fluids and they are ranging from 62% to 81 %. The reasons for this improving have been addressed and explained by measuring the viscosity of these nano fluids and interfacial tension.

This research examines and analyzes the new outcomes from implementing these nanomaterials for improving oil recovery over the traditional methods. Ultimately, the knowledge gained from this work can be used to interpret and define the nanofluids improvement mechanisms, and projected a roadmap for ongoing and future work.
Water Conformance Control Approach for Mauddud Reservoir, North Kuwait Field
Authors: Ashkanani Fatma , Al-Ajmi Moudi , El-Daoushy Ahmad
Published: October 2015

North Kuwait Conformance Control task force team initiated to control the uniformity of the flood front of the injected drive fluid during an oil recovery flooding operations, which helps to reduce unwanted water production, enhance recovery efficiency, and to satisfy the reservoir management and environmental objectives. In addition, it will delay pre-mature water breakthrough at the producers on short term and maximize the water flood recovery on long term.

Initiatives & new approaches made by field development NK to improve the water cycling and poor sweep occurred as a flood matures with time, which considered as one of the key challenges to control the water production increase. Production/injection philosophy was redeveloped to add further strengthen our ongoing water flood performance improvement integrated efforts. Tackling the high water cut wells, drilling efforts to horizontal sidetracks, and workover of vertical wells conform to the new waterflood strategy have been taken up as ongoing efforts. In addition, some runs made using MA dynamic model to generate prediction scenarios to investigate the response of MA conformance control. The runs showed a positive impact which improve the oil recovery & reduce the water production subsequently.

Most of the key producers showed an excellent response as a result of water conformance control application. Many successful cases were observed which have been resulted in water cut reduction and oil production increase. Continues monitoring and follow up is required to achieve the desired well rates so as to reduce cycling of the injected fluid while maintaining or even increasing oil production. Water and oil production responses are under a continuos monitoring as well as injection analysis and reservoir pressure response.
The Effect of Ultrasonic Waves of EOR on the Relative Permeability Curves
Authors: Ragab Adel M. , Fouad Snosy M..
Published: October 2015

Ultrasonic waves have been used for improved oil recovery especially from the marginal well in so many area all over the world. The main mechanisms of the seismic pulses from ultrasonic waves is to supply oil molecules by energy to overcome capillary forces there by restructuring the relative permeability curves increasing the oil mobility. Monitoring these changes is very important for increasing the mobility of oil even after residual oil saturation achieved by water flooding.

The present work discusses and investigates the laboratory effects of ultrasonic waves on the relative permeability curves by measuring it before and after applying the pulse waves. Six core samples was used from Egyptian homogeneous reservoirs, these cores are sandstone and carbonate, their permeabilities range from 67 to 460 md. In this technique. Acoustic ultrasonic waves of 500 KHZ was applied in cores is this research. At this frequency, the fluid vibrates out of phase with the solid and is forced out through the pore structure in the agglomerate. This relative fluid motion to exert high viscous stresses at the particle-particle contact points which leads to fracture of the agglomerate and the dispersion of the individual particles.

The interaction of the generated waves with the fluids in the pores causes changes in relative permeability of the rock to oil and water, which may lead to improve the rate of oil production. Therefore, the results showed that applying ultrasonic waves has a higher effect in low permeability reservoirs (75 md to 460 md) and can mobilize additional quantity of crude oil. The fractional flow curve changes are also addressed and analyzed after ultrasonic wave applications.

The ultimate aim of this research is to investigate the effect of the ultrasonic wave as new proposed method to improve oil recovery by changing the relative permeability curves of the reservoirs. Moreover, it can be used to determine and investigate the recovery mechanisms for improving oil recovery.
GeoSteering Through Challenging Fractured Limestone Reservoir becomes Achievable Utilizing High Definition Multi-Layer Boundary Mapping Technology - A Case Study from a Deep Gas Reservoirs
Authors: Al-Ajmi Saad A. , Pattnaik Chinmaya , Al-Dawood Ahmed E. , Dashti Qasem , AlFailakawi Abdul Aziz , Chakravorty Sandeep , Chandan J. Keot , El-Derini Khaled M.
Published: October 2015

Kuwait Oil Company is currently engaged in an early phase development of deep sub-salt tight naturally fractured carbonate reservoirs. These reservoirs has been tested and found to be gas bearing. They are uniquely characterized by dual porosity nature where natural fracture network systems are the primary flowing mechanism. The foremost challenge to produce from these reservoirs is the wellbore interaction with the natural fracture network systems. Despite drilling around 85 vertical and slightly deviated wells in this large challenging HP/HT reservoir complex, understanding and characterization of fractures is a challenge in the absence of horizontal wells, though fracture understanding has improved over time through careful integration and interpretation of logs, core, and seismic data. To achieve the dual objective of characterizing the fractures and to boost production, asset team recently embarked on the strategy to drill horizontal wells targeting these challenging tight reservoirs. As a fit for purpose solution to address these challenges, "High Definition Deep Directional Multi Boundary Detecting Technology" was incorporated in the drilling plan so that horizontal producers could be geosteered in the desired target intersecting as much fractures as possible. This technology, an advancement on the 1st generation "Distance to Boundary" technology is characterized by its extended capability to detect multiple bed boundaries based on resistivity contrast up to 20ft around the wellbore. The significantly improved new multilayer stochastic inversion also solves for structural dip along the wellbore azimuth (longitudinal dip). In the lateral section, this technology successfully mapped the reservoir roof as well as multiple thin intra layers inside the target reservoir along with information on longitudinal dips which helped immensely to optimize trajectory inclination and spatially position the wellbore across different layers as per plan. Apart from detecting reservoir boundaries, the inversion also mapped conductive and resistive fractures cutting wellbore at high angle for the first time, while trajectory was drilling across a fracture corridor. This further added confidence to geo-steering while drilling as wellbore cutting through such a fracture corridor was highly anticipated in predrill planning. Drillpipe conveyed borehole images acquired after drilling the well confirmed the presence of large swarms of fractures detected through inversion.

The effective integration of data from different fields in a single platform, like LWD logs, boundary information, dip information, drill cuttings information and decisions taken based on the interpreted information paved the way for the successful drilling of this well and achieve the predrill objectives.