bluuebunny/crossref_metadata_2025_split huggingface dataset:
Wellbore Stability Optimization in Shale Gas Wells by Integrating Geomechanics and Drilling Practices
Authors: Khan Safdar , Yadav Anurag 
Published: October 2013

ABSTRACT
Horizontal wells with multi-stage fracturing are typically used in shale gas plays for them to become economically feasible to produce gas. Two distinct types of challenges are faced while drilling horizontal wells in shale, first type is wellbore instability potentially leading to stuck pipe incidents in the build section, and the second type is loss circulation, potentially compromising well integrity in the lateral section. This paper presents a workflow on handling these challenges effectively by integrating geomechanics with efficient drilling practices.
Formation Prediction Model based on Drill String Vibration Measurements Using Laboratory Scale Rig
Authors: Esmaeili Abdolali , Elahifar Behzad , Fruhwirth Rudolf K. , Thonhauser Gerhard 
Published: October 2013

Abstract
Characteristics of formations usually cause changes in the drilling parameters such as weight on bit and drill string rotational speed as well as drill string dynamic behavior. When the drill bit breaks up formations, some of the energy dedicated to drilling is transmitted to the drill string as axial, lateral and torsional vibrations. Although these vibrations are affected by the drilling parameters, it has been experienced that vibration measurements can be used to evaluate formations during drilling a well. For this purpose a laboratory scale drilling rig was used to perform numerous experiments. During the drilling operations, several drilling parameters as well as vibrations with three-component accelerometers attached to the drill string were recorded continuously. Numerous uniform concrete and rock samples were drilled by a double roller cone bit. The uniaxial compressive strength of all concretes and rocks were measured prior to the experiments. The tests were executed using different combinations of weight on bit and rotary speed.
For a subsequent evaluation statistical features were extracted in a first step from the recorded data in both, the time domain and the frequency domain. Those features formed the base for the formation classification by linear and non-linear models. Although linear models like Bayesian inference are not suited for that challenge, it turned out that non-linear models like neural networks provide excellent results in both, the training and the test data-set. Finally, the application of parameter selection methods showed that mechanical specific energy and rate of penetration in combination with higher order frequency moments of all recorded vibration types play the major role in the formation classification.
ADCO Life Protection Rules, a Powerful Tool in Enhancing Drilling Road Safety Performance
Authors: Boucif Mustapha Nasr-Eddine , Al Yaaqoobi Rahma Ateeq , Khalid Jamil 
Published: October 2013

Abstract
During the past decade Vehicle Accident Frequency (VAF) has been steadily improving in an exponential way achieved a world class performance of 0.04 VAF in 2009. Following a slowdown in performance in 2010 and an alarming increase in the first quarter 2011 a new strategy was adopted to bring ADCO drilling road safety performance back to its excellent standard. Immediately following the fourth road accident in the first quarter of 2011, a workshop was organized by the Drilling Division leadership involving all drilling contractors to study the way forward and to discuss all the accidents. Each Manager whose company was involved in an accident had to present the investigation outcome and the way forward. Brainstorming followed the presentations and a plan was set in place.
Part of the plan was to have a stand down for safety for two hours in all the rigs and a high-profile tour with road safety as theme to show ADCO and contractors management commitment to safety and concern with the regard to this alarming increase of accidents. All the rigs were fully shut down for two hours on the same day and mixed management teams from both ADCO and contractors visited all the rigs with the purpose to talk with rig personnel and also to show that safety takes priority over speed of operations. To further improve our safety performance and to keep our employees and contractors safe by focusing on compliance and tackling the cultural issues that can lead to unsafe behavior, ADCO Drilling Division implemented ADCO mandatory 9 Life Protection Rules (LPR). These rules reinforce what employees and contractors must know and do to prevent serious injury or fatality. Drilling Division implemented the LPR in 2012 with special focus on item 1: Road Safety.
As a results of The road safety programme introduced by ADCO Drilling Division in 2012 the Vehicle Accident Frequency went sharply down reaching a world class performance of 0.1, in 2012 and zero injuries; one of the lowest in ADCO Drilling history. Using the same approach in 2013, we have recorded 0.06 VAF in ADCO remote fields: Shah (Brownfield), Qusahwira and Mender (green fields), another indication that ADCO has set a strategy that did enhance the road safety performance and can be used even in remote area with success.
EOR in North Kuwait-From Concept to Field Test
Authors: Al-Saad Bader , Pathak Ashok Kumar , Tiwari Sanhita , Baroon Bodoor 
Published: October 2013

Abstract
Ambitious leadership, integrated planning and availability of resources have seen unprecedented growth in development activities of North Kuwait reservoirs over the last 4-5 years. As a result of this production has significantly grown but so have production challenges. New ideas and ways to enhance production and reserve growths are being discussed and tested. In this context role of Enhanced Oil Recovery (EOR) has been critically examined and steps are being taken to have a pragmatic action plan in place to achieve strategic objectives.
North Kuwait has been endowed with a mix of clastic and carbonate reservoirs of that are highly productive. These reservoirs are at different stages of depletion and their development plans are constantly tuned to enhance oil production and reduce water cut. KOC's approach to EOR plans is inclusive. It is looking at not only mature clastic reservoirs like Lower Burgan but also at Mauddud, Upper Burgan and Zubair reservoirs that are in middle stage of their development bypassing the conventional route post-secondary recovery.
Considering previous work and recent developments in the field of EOR, chemical methods and miscible Carbon-Di-Oxide (CO2) processes were shortlisted for more in-depth investigations. Subsequent extensive simulation studies place incremental oil recovery estimates using the results of specifically customized Surfactant Polymer (SP) formulation for Sabiriyah Mauddud in excess of 25% over the CO2 WAG (Water Alternating Gas) process.
In view of the significance of these results to North Kuwait's production plan EOR program is being fast-tracked. It is now at a point where a pilot is being planned in Sabiriyah Mauddud to field-test KOC's first SP flood in the next 1-2 years. Action plan is being finalized with all activities, milestones and deliverables. The project activities are being closely monitored to ensure timely completion of key tasks by different groups. For other reservoirs risk-opportunity matrix is being developed to understand the pitfalls and potential of shortlisted methods. It is expected that this work plan will enable KOC to realize its vision of getting first EOR oil from North Kuwait by the turn of 2016.
HSE Challenges While Testing and Completion of High Sour HPHT Exploratory Wells
Authors: Subban Packirisamy , Duggirala Vidya Sagar , Ayyavoo M.. , Al-Salali Y.. , Al-Ibrahim A. R. 
Published: October 2013

Abstract
Kuwait Oil Company (KOC) is fully committed to protect the health and safety of its people and the environment. Strict adherence to the KOC HSE policies and procedures helped safe execution of critical well testing and completion operations of sour High Pressure High Temperature (HPHT) exploratory wells.
This paper describes safety challenges, H2S related risks, and methodology adopted to achieve safe and successful well-testing operations with deep drilling rigs in extreme sour HPHT environmental conditions. Critical operational equipment and safety precautions to be followed prior to and during well testing will also be discussed in detail.
Deep HPHT wells with sour environment continue to challenge the execution of well testing and completion operations, especially when wells are of exploratory nature. Wells drilled in deep Jurassic section (14,000'-17,500') having bottom hole pressure more than 10,000 psi, bottom hole temperature higher than 280°F and high sour content(up to 35% H2S) are considered for this case study. Almost 30 exploratory wells under similar environmental conditions have been drilled and tested with deep drilling rigs in different fields in the state of Kuwait. Drill Stem Testing (DST) technique is being used to test the targeted formations.
Well related production testing operations like Perforation, Coiled Tubing, and acid stimulation warrant high HSE standards and technical precautions. Every HPHT well is unique and demands special attention when it comes to the selection of critical safety equipment and other safety requirements such as Personal Protective Equipment (PPE), H2S monitors, wellhead equipment, sealing material, flow control equipment and surface safety valves (SSV) with emergency shutdown switches.
Even in such hostile environment, with meticulous planning and testing strategies, KOC could overcome all the challenges and all HPHT sour wells were safely tested without any incident. Commitment to HSE was given the highest priority during testing of sour HPHT wells with great emphasis on personnel safety.
Future Challenges Due to the Increase Produced Water in Upstream of Oil and Gas Industry
Authors: Al-Jabri Saleh M , Al-Otaibi Mohammed , Al-Khaledi Sadoun 
Published: October 2013

AbstractAn overview on the future challenges that the oil and gas production is facing in regards to the continuous increase of the produced water (effluent water), the volume of effluent water associated with crude oil production has been increasing due to the maturing of the oil fields, field developments forecasts can be used in order to estimate this increase, and develop the required mitigation methods. This paper discuss the future challenges which will occur due to the rapid increase of the produced water in the upstream oil and gas industry and demonstrate variances between possible solutions.This increment in the produced effluent water shall develop a huge challenges in achieving the required oil targets due to the limitation in capacities of the separation equipment's at the existing facilities, also the produced water handling facilities shall face a challenge in delivering this quantum of produced water to the produced water disposal/ injection plants. Limitation of available spaces at the existing facilities will be a challenge as well.To face such challenges several technology options were explored and a comparison study was done to compare among those options based on applicability and compatibility, where we can see that a adopting new separation technologies by knocking- out the free water using a portable separation unit can be an advisable solution, also avoiding the issue of limitation in space at the existing facilities by using a compact separation units or by upgrading the existing facilities and enhancing the separation at those facilities, We shall touch other experiences and compare between different technologies allowing us to share the knowledge and Skills from around the world.
Novel Asphaltene Inhibitor for Direct Application to Reservoir
Authors: Leonard Geoffrey C. , Ponnapati Ramakrishna R. , Rivers Gordon T. , Wiggett Adrian J. 
Published: October 2013

Abstract
Destabilization of asphaltenes within crude systems often occurs inside production tubing, but aging reservoirs, especially those flooded with supercritical CO2, can suffer asphaltene precipitation within the reservoir. Conventional asphaltene treatment programs entail inhibitor chemicals dosed into produced fluids via a capillary injector, which insufficiently guards against asphaltene deposition occurring within the reservoir. Such deposits, either far within the reservoir or near the wellbore, alter reservoir characteristics, production economics, and potentially the lifespan of the well. This paper presents a novel asphaltene inhibitor molecularly tailored to adsorb to formation surfaces upon application and then slowly desorb and remain in produced fluids to mitigate the flocculation of asphaltenes. Coreflood test results indicate the new asphaltene inhibitor for ‘squeeze’ applications resides within field core samples for approximately twice as long as the benchmark asphaltene inhibitor. Importantly, the new asphaltene inhibitor squeeze chemistry maintains equal inhibition performance compared to incumbent asphaltene inhibitors.
Do Advanced Drilling Techniques Really Add Reserves and Enhance Recovery?
Authors: Qutob Hani , Retalic Ian 
Published: October 2013

Abstract
With the majority of today's "new" hydrocarbons increasingly found in technically challenging, complex and in many cases lower quality reservoirs, it's long since been agreed there is no more "Easy oil". It's that fact, coupled to the industry wide challenges associated with conventionally drilled wells in mature and depleted reservoirs which have led in recent years to the very significant advances seen in the Advanced Drilling Techniques (ADT) and Technology arena.
ADT provides a suite of tools and techniques which have enabled the technical and commercial development of numerous oil and gas reservoirs worldwide which would have not otherwise been exploited. ADT comprises of the following techniques: Managed Pressure DrillingUnderbalanced DrillingCoiled Tubing DrillingThrough Tubing Rotary Drilling (Conventional and HPHT)Subsea Through Tubing Rotary Drilling
According to one recent industry report some 67% of the world's daily oil production comes from mature fields, therefore in order to not only sustain but improve upon current production levels, field life extension is not optional but an absolute necessity. Historically however, most Operators due to cost and complexity of well delivery have not fully exploited their mature assets consequently failing to reach their full potential. Therefore, in order to not only sustain but increase current production levels to meet the increasing demands, operating companies must pay greater attention to their mature fields and their resources development options.
The above coupled to the fact that in almost every conventional drilling operation there is risk, a potential to; damage well productivity (formation damage), encounter lost circulation; suffer differential sticking and many other related conventional drilling problems any of which can be exaggerated in a mature drilling environment as a function of depletion. Its here, when applied with an expert system for candidate reservoir screening, technique selection and improved reservoir evaluation technologies, ADT provides realizable and available EOR and IOR options in accessing ‘conventionally’ or commercially stranded reserves. Further, when fully coordinated with the neseccary subsurface disciplines an ADT solution will add measurable value by; improving production, enhancing ultimate recoverable reserves, even possibly reduce overall development cost all improving net present values.
Popular perception is we need new technology to sustain and drive the industry forward in meeting the global demands placed upon it; in truth if we look; much of the required technology is available now. The thing we, the industry, need most is the opportunity and most importantly the courage to deploy it. This paper will challenge us in our perceptions and highlight how we can mitigate the risk applying smarter drilling options such as those offered by Advanced Drilling Techniques in the hydrocarbon bearing formations.
Selection Process for Optimum Sour Field Surface Production Scenario - Minagish Reservoir, Burgan Field
Authors: AL-Faresi F. A. , Bond D. J. , Majeed M. Abdul , Al-Naqi M.. 
Published: October 2013

Abstract
Every field development plan should go through a ‘quantitative’ option ranking process in order to select the optimum scenario for developing that field. Doing so efficiently will help in identifying the optimum project concept for the delivery of value to Kuwait Oil Company.
An example of where such a ranking process was essential was in the development plan for the Minagish Reservoir in the Greater Burgan Field. Within South-East Kuwait asset, this reservoir has to be treated ‘unconventionally’ since its Hydrogen Sulfide (H2S) concentration is high, in relation to the ability of the existing facilities to handle sour crude production. This has contributed to the low recovery factor from this reservoir which has been on production for over 50 years. Therefore, a new surface development plan for this reservoir had to be generated to assist KOC in meeting/sustaining its production targets for the year 2020 onward.
The choice for optimum surface production scenario came through a ‘quantitative’ ranking process. This can be broken down into a number of separate steps: Agree to the objectives of the project and the value added to KOC.Capture production options and development concepts to meet the objectives of the project. This was done through a number of brainstorming sessions. The team involved came from several areas of the company with different backgrounds.These options were screened for viability for implementation.Agree to the ranking criteria for the project to determine appropriateness in terms of delivering value and meeting objectives.Rank each of the chosen options against the selection criteria agreed. This will provide the most appropriate concept(s) to be considered for detailed engineering.
Such a ranking process was particularly useful in this case because of the number of options available and broad range of project objectives. It is recommended to consider this method for ranking options in future projects. This paper describes the facility selection process implemented for the Minagish reservoir development plan.
Integrated Multidisciplinary Approach for Training New Recruits in Reservoir Management and Field Development
Authors: Alzankawi Omran , Alwazzan Roqaya , Shuber Hussain , Al-Ghareeb Aisha , Kotecha Rohit , Mudavakkat Anandan , Bardalaye Jayanta , Hayat Laila , Sinha Satyendra , Capello Maria A , Al-Hamoud Jamal 
Published: October 2013

AbstractAs part of KOC strategy to develop the technical skills of the new recruits this paper will present a series of best practices related to decision workflows during drilling of horizontal wells through a recognized multidisciplinary team which optimized the preparation level and knowledge standard for the young generation through practical workshop and in short period.The best practices identified included aspects related to reservoir management, location selection, subsurface characterization and drilling specifics. Those were the key elements in the preparation of the technical training with the support of a multidisciplinary team that proved beneficial to the decision processes and issues faced during drilling in real time workflows. However optimization of a well needs skill, knowledge, right vision and experience, hence the results of the extensive drilling campaign and different cases of horizontal wells allowed the establishment of a practical training workshop protocol using actual acquired data for the planning, follow-up and assessment of drilling operations, which is now used in Fields Development South and East Kuwait. The practical workshop encompassed two case histories of horizontal wells where good decision procedure resulted in avoiding complications during drilling and effectively optimized most of the drilling path.This practical, interactive workshop was successful in developing with an integrated framework, the necessary skills in the participants, in all technical disciplines involved, namely Geosciences, Petroleum Engineering and Reservoir Engineering, in a pioneer effort of the Greater Burgan teams, not used before in KOC for training.The impact of this workshop was to enhance the experience of the young professionals in Petroleum Engineering, Geoscience interpretation and Reservoir Management, as well as to build their integrated knowledge on horizontal drilling for the benefit of KOC, across all Directorates and possibly applicable to other oil companies.
Effective Down Hole Gas-Liquid Separation to Eliminate Liquid Loading Problem in Gas Wells
Authors: Patel Harsh , Shah Deep 
Published: October 2013

Abstract
Currently, many preventive measures as well as artificial lift methods are available to deal with liquid-loading problem in gas wells but they all have their own limitations. The plunger lift, considered to be the most efficient technique, requires minimum gas liquid ratio of 4000 SCF/barrel. Below this critical GLR value, available lift systems are not suitable or economically not viable.
The purpose of this research paper is to propose a new universal solution which can tackle liquid loading problem very efficiently and to evaluate it in comparison to the current methods. The proposed solution provides an effective gas-water separation at the bottom hole with facility to either lift the accumulated liquid or to re-inject it into any of the non-producing porous formation lying bellow the producing zone. The gas is produced through tubing-casing annulus with an aid of compressor if necessary. This liquid re-injection neglects the necessity to lift and process this water, which results in reduced treatment cost. In case of unavailability of disposable formation, the accumulated liquid slugs can be removed periodically by beam pumping or Electrical Submersible Pumping through tubing.
The prima facie analysis of this method suggests that it is very effective, cost efficient and unlike current artificial lift methods, it is not restricted by any of the operational parameters such as GLR. It will help in recovering huge amount of untapped gas which is still lying beneath the earth.
Almost every gas well in the world faces the problem of liquid loading at some point of their production life. Failure to mitigate this leads to a premature abandonment and hence economic losses. To cope up with the ever-increasing energy demand, it is essential to extract maximum possible gas from the reservoirs and this method is surely going to help in that direction.