bluuebunny/crossref_metadata_2025_split huggingface dataset:
Successful Water Shut-off Through Innovative Data Acquisition and Phased Planning
Authors: Samuelsen Eivind H. , Frederiksen Rene A. , Noer Jesper , Hartvig Sven K. , Haugan Are 
Published: July 2010

Abstract
This paper demonstrates how innovative data acquisition, phased planning and world class placement of filler material in a short circuit lead to a successful water shut-off restoring 477 m3/day (3,000 BOPD).
Hess operates the South Arne Field located offshore Denmark. Two flank horizontal wells, a producer and a water injector, started short-circuiting water via an abandoned sidetrack. High pressure (517 barg) water from the injector flowed directly into the producer (172 barg) killing the oil production.
The wells’ horizontal length is 3 km and is completed with a cemented liner. The liners are subdivided into 17 zones with production/injection tubing, iso-packers and sliding sleeve doors. Each zone has been stimulated with acid fractures.
The vital part of the data acquisition was multiple tracer tests from different zones at different production and injection ratios, which increased the tracer recovery from 15% to 100%. In addition, tracer data revealed transit time, sidetrack volume and number of paths; all crucial information for a successful water shut-off. A gel mimic test was performed to account for differences in rheology.
Pressure and temperature logging tools in the wells provided the pressure and temperature gradient along the sidetrack, which was crucial data for placement of the temperature sensitive filler material.
The decision was to approach the challenge in three phases; firstly, data acquisition; secondly, interpretation of data, filler material laboratory tests, design of job; thirdly, implementation of the water shut-off. This proved to be advantageous as it allowed time for appropriate adjustment and planning of the complex setup.
The 19 m3 (120 barrels) of filler material was mixed on the platform and pumped into the injection well tubing while producing from the production well at controlled condition with one optimal sliding sleeve door open in each well and an optimal production/injection ratio The temperature of the filler material increased as it travelled to its final destination in the sidetrack leaving a 450 m (1475 ft) solid isolation plug.
One year after the water shut-off, oil production has increased from 0 to 477 m3/day (3,000 BOPD) saving an expensive and challenging re-drill.
This project underlines the importance of spending time and money, upfront, on innovative acquisition and planning to increase a project's chance of success.
Utility Calculation Method of New Four-Parameter Rheological Model for Drilling Hydraulics
Authors: Wang Guo , Fan Hong H. 
Published: July 2010

Abstract
The prediction of pressure losses is very important in many oil-field operations, including drilling, completion, fracturing, acidizing, workover and production. In this study, a utility hydraulic calculation method has been developed that requires as input the raw fluid rehological data and relevant hydraulic parameters. This new method is based on three important developments.
First, this paper presents a new and powerful rheological model, named four-parameter model. A brief introduction was given to the determination of rheological parameters. Calculation model for rheological parameters was built based on regression method. Using a variety of data from literature, it is shown that four-parameter model could precise represent the rheogram of the time-independent fluids.
Second, a generalized hydraulic calculation model is developed based on power law extension method, which is independent of the form of the rheological model of choice. For laminar flow, pressure drop formula is derived based on characteristic method of pipe flow. And turbulent pressure loss is calculated by semi-empirical formulas. Flow regime determination method is established by quoting generalized flow behavior index.
Third, for pressure drop calculation precisely, the approach includes the additional pressure loss due to the effect of tool joints, accommodates drilling pipe rotation effects and accounts for the effects of annular eccentricity. Furthermore, simple, explicit and general formulations for approximation pressure losses over measurement while drilling tools are also presented to augment the suite of expression required for complex hydraulic calculation.
The predictions of the developed method have been compared with several sets of experimental hydraulic data from different sources. The tested cases include laminar and turbulent flow of various drilling fluids in both pipe and annular geometry. The generalized hydraulic calculation model is shown to be quite accurate and superior to those obtained by the currently available standard techniques.
First Successful Selective Stimulation With Coiled Tubing, Hydrajetting Tool, and New Isolation Sleeve in an Openhole Dual-Lateral Well Completed in a Saudi Arabia Carbonate Formation: A Case History
Authors: Garzon F. O. , Franco C. A. , Ginest N. H. , Sierra L. , Surjaatmadja J. B. , Izquierdo G. 
Published: July 2010

Abstract
Drilling and completion of extended reach (ER) or multilateral wells (MLT) in open hole carbonate reservoirs to maximize the reservoir contact and exploitation has become routine in Saudi Arabia. Initial deep gas development wells were conventional vertical wellbores that were perforated an either acid matrix or fracture stimulated. Experience with the more complex ER and MLT well completions has shown that these wells also require stimulation to remove induced damage or to enhance well productivity. Selectively accessing and stimulating these complex well types completed with open hole laterals is extremely challenging utilizing existing conventional intervention technologies.
A recently drilled dual lateral well completed in the Khuff-C formation with open hole horizontal sections exceeding 3,000 ft was successfully selectively stimulated. This paper describes how each lateral was accessed with coiled tubing (CT) and selectively stimulated using a hydrajetting tool and a new isolation sleeve, which was used for the first time in the world. The excellent post-treatment results achieved are also discussed.
Corrosion Control of Drilling Tools Through Chemical Treatments – Effectiveness and Challenges
Authors: Asrar Nausha 
Published: July 2010

Abstract
With increasing demand for energy, the production of oil and gas must increase. However, increasing production is challenging because the wellbore fluids in many new fields are typically multiphase in nature with harsh chemical compositions and conditions, such as high hydrogen sulfide, carbon dioxide, and occasionally dissolved oxygen, in a high temperature and pressure environment. All this makes corrosion control a major concern, especially in the present challenging economic climate, where the risks and cost associated with corrosion may have significant impact on Health, Safety and the Environment (HSE), capital expenditure (CAPEX) and operation expenditure (OPEX) in oil & gas exploration and production. This paper addresses the chemical treatments of drilling mud for corrosion control. Corrosion mechanisms, such as mud deposit attack (pitting), corrosion due to corrosive gases of formation, stress corrosion cracking, and microbiologically influenced corrosion (MIC) are reviewed to emphasize the failure mechanisms through which the drilling fluid parameters, such as, dissolved oxygen, pH, hydrogen sulfide, carbon dioxide and chloride contents may aggravate the corrosion problem and adversely affect the reliability of the downhole equipment. These corrosion issues are addressed by design and control options such as material upgrade, coatings, cladding, and chemical treatment. However, the focus is on chemical treatments, the mechanism through which they can effectively control corrosion and their limitations. Finally, prevention and mitigation measures are discussed to address the limitations of chemical treatments, such as control measures by the drilling company for mud treatment and the development of sensors for monitoring mud chemistry during drilling operations.
Research of Conductor Setting Depth Using Jetting in the Surface of Deepwater
Authors: Jin Yang , Shujie Liu , Jianliang Zhou , Pingshuang Wang , Haixiong Tang , Junfeng Luo , Bailing Zhang , Changsuo Zhou 
Published: July 2010

Abstract
The tripping technology using jet conduit in construction of deepwater drilling is a key technology, In this paper, the relationship between the jet catheter lateral friction and the properties of the seabed soil is studied through theoretical research and analysis and field simulation test, The relation model of lateral friction in the sandy soil and clay conduit and the consolidation time has been established. Combined with construction process of deep-water jet catheter, an analysis of force situation during the process of drilling pipe jet was carried out, and a calculation model of the tripping in depth of jet catheter. To combine a deep-water exploration well in the South China Sea with the specific circumstances of, from the depth into the mud of drilling jet catheter, drilling assembly, Optimization of drilling parameters and the main points of the construction of jet catheter tripping in, Etc. Explored the technical skill under the jet method surface casing, shows the construction of drilling jet catheter site specific measures.
Pipework and Vessel Review and Risk Based Assessments of the North Sea Forties Assets
Authors: Barson R. , Spicer K. 
Published: July 2010

Abstract
The North Sea Forties assets, consisting of five platforms, have been in operation for 35 years. Extensive exploration of the Forties field in 2003 indicated that the field life could be extended by 20 years. Consequently, the Operator made substantial investments in these assets for the necessary upgrades to improve efficiency and infrastructure integrity.
The pipework and vessel information and inspection history for the assets was stored in an asset database. This database had not been updated for several years and therefore could not be used as an efficient inspection tool. For the Operator to introduce Risk-Based Inspection (RBI) to the assets, a thorough review of the topside pipework and vessel information was required.
The main scope of work was: An update of the pipework and vessels equipment list to include upgrades and archiving removed or redundant itemsCompiling a deadleg registerAllocating pipework to corrosion circuitsIdentifying insulation status changesPerforming Risk-Based Assessments (RBA) on corrosion circuits and vessels to facilitate RBI
Comparisons of the assets’ updated P&IDs with the database equipment list were made to identify the new, redundant or removed items and other changes.
The updated asset equipment lists were uploaded into the database, overwriting the outdated information. It was then possible to start the RBA process using the database.
The RBA sessions were attended by a panel of experts; the Integrity Authority, two Corrosion Engineers, an Inspection Engineer and a Pressure Systems Engineer. Qualitative RBAs were performed on all corrosion circuits and vessels with only limited records of inspection history and with reliance on the knowledge and judgment of the experts.
On completion of the topside assets update/review, together with the RBAs, the Forties field Operator was able to perform full Risk-Based Inspections (RBI) on pipework and vessels, thereby providing an improved operational regime.
Possibilities of the Methane Utilization from Mined and Unmined Coal Seams in Poland
Authors: Stopa Jerzy , Nawrat Stanislaw , Rychlicki Stanislaw 
Published: July 2010

Abstract
The potential in coal seams gas resources in Poland is estimated to be similar to known conventional reserves (about 150 bln s.cu.m) but present efficiency of utilization is much lower. Many coalmines utilize this gas for a small-scale heating and electricity generation, but global utilization efficiency is as low as 60%. In Poland, methane is recovered mainly for safety reasons from coalmines. This paper presents new possibilities for methane production from abandoned coalmines and from unmineable, deep coal seams. In the first case the gob gas ventholes can be drilled from the surface, in the second case multilateral wells technology can be employed. In the paper, the simulation models of mined and unmined coal seams are presented and discussed. The results are evaluated from both technical and economical point of view. Economical analysis showed positive NPV and IRR=10%. Two case studies presented in this paper show that both abandoned coalmines and unmineable coal seams could be effectively utilized for coalbed methane production using advanced drilling technologies. During the last decade many coalmines over the Europe have been abandoned for both economical and environmental reasons, others are in the terminal state of production. However, some of these mines still contain large resources of methane that could be used for the local purposes like heating or electricity generation. The case study of the Moszczenica coalmine in Poland, including computer simulation of the coal and methane production shows that gob gas can be successfully recovered using new wells drilled from the surface. Presently, the deep unmineable coal seams are often not utilized from economic reasons. The case study presented in this paper shows that they can be effectively utilized for coalbed methane production using advanced drilling technologies like multilateral wells.
Comparison of Different Deliverability Testing Techniques in Low Permeability Gas Reservoir and Its Impact on the Absolute Open Flow (AOF) Estimation
Authors: Khalifa Mohammed , Yemez Ivan , Stigliano Horacio , Vicente Sekulin Mario , Angulo Reinaldo 
Published: July 2010

Abstract
Several deliverability test techniques are being used in the oil industry to generate a reservoir inflow performance relationship (IPR). The IPR curve describes the relationship between surface production rate and the flowing pressure at the bottom of the well (BHFP). The Absolute Open-Flow potential (AOF) represents a hypothetical gas flow rate that may be produced if the BHFP value were equivalent to the atmospheric pressure, i.e. the maximum flow rate that the reservoir may produce.
The most commonly known techniques for deliverability testing are: Flow-after-flowIsochronalModified IsochronalSingle-point
Although, these techniques are aimed to evaluate the production capacity of wells, most of them (the Isochronal, Modified Isochronal and Single-point tests) were developed to reduce the flared/vented gas and to minimize well testing cost. The flow-after-flow method requires stabilized flow for each of the flow periods, while the rest of the techniques only require stabilized flow at the last flow period test.
In this study, a radial simulation model was used to simulate the flow behaviour observed during application of the different well deliverability techniques mentioned above and to analyze and compare their flow stabilization times. These simulation results indicate that the stabilized flow condition is the main factor which influences the AOF results for any of the deliverability testing techniques used. Furthermore, the results emphasize that the use of a non-stabilized flow test may lead to an over estimation of well deliverability, especially for low permeability reservoirs.
New Generation Software Integrates Intrusive and Non-intrusive Systems for Corrosion and Sand/erosion Monitoring
Authors: Wold Kjell , Hopkins Sean , Jakobsen Tommy , Lilleland Svein Erik , Stoen Roar , Brandal Øystein 
Published: July 2010

Abstract
On-line corrosion and sand/erosion monitoring increases the amount of data to be handled significantly, and new monitoring technologies also generate more complex information than before. The importance of reliable and efficient systems for data management and for the reporting and analysis of monitoring data has therefore never been higher.
Roxar has developed software which combines intrusive and non-intrusive systems for corrosion monitoring, as well as intrusive and acoustic systems for sand/erosion monitoring into one integrated solution. Together with new measurement technology features, the new system will improve user ease-of-use and the reliability of data, in particular for the non-intrusive field signature method technology.
This paper will describe and present field data from the first on-line electric field signature systems, and demonstrate how the new software can improve the use and presentation of the data. Finally a new measurement feature for electric field signature measurements will be introduced and the paper will demonstrate how this feature can improve the detection and quantification of localized corrosion and sand/erosion attacks in all directions.
The paper will provide an overview of the move towards on-line and integrated corrosion and sand/erosion monitoring solutions; an overview of today's sand monitoring and corrosion measurement technologies; the growth of the electric field signature method (FSM); and details on the new software. The first field installation of the new software was carried out at Statoil's Heidrun field. Experience and field data from this installation will be presented and discussed.
Changing the Injection Water on the Blane Field, North Sea: A Novel Approach to Predicting the Effect on the Produced Water BaSO4 Scaling Risk
Authors: McCartney R. A. , Burgos A. , Sørhaug E. 
Published: July 2010

AbstractThe Blane Field, North Sea, has one injection well and two production wells and is tied back to the Ula Field platform. The original scaling risk assessment was based on injection of platform produced water (PW) with minor seawater (SW) (~90:10 PW:SW). However, after injection of 25:75 PW:SW for only 6 weeks, a change in operational circumstances on the Ula Field meant that only 10:90 PW:SW injection water could be supplied for the next 18 months. There was a risk that this might result in unmanageable BaSO4 scaling conditions in the production wells but the alternative would be to cease injection, leading to reservoir pressure decline and loss of oil revenues.The need for a rapid decision negated the use of reactive transport reservoir simulations to predict the future BaSO4 scaling risk under the new injection scenario so a novel, alternative approach was adopted. A history matched ECLIPSE model served as the basis for predicting the types of water entering the production wells over time and their rates. A 1-D reactive transport model was then used to predict the Cl, Ba and SO4 composition of these waters after accounting for the effects of reservoir reactions. These results were integrated in a spreadsheet to provide predictions of Cl, Ba and SO4 concentrations in the produced water from each well over time.The results for future injection water scenarios indicated that the scaling risk would increase over time in the wells but, due to deposition of BaSO4 and CaSO4 in the reservoir, the BaSO4 scaling risk would be manageable even allowing for uncertainties associated with this approach.Based on these results, and those of associated studies, a decision was made to continue water injection resulting in avoidance of loss in oil revenues. This novel scaling prediction approach may be useful on other fields where reactive transport reservoir simulations may not be possible.
Advances in Subsea Well Intervention BOP Qualifications
Authors: Deshotels S. J. , McClanahan P. , Douty J. 
Published: July 2010

Abstract
Performance Verification Testing (PVT) is performed on prototypes on production models to verify the performance requirements specified for temperature, pressure, load, mechanical cycles, and standard test fluids are met in the design of the product.
I will outline the PVT requirements as given in API 6A (ISO 10423), API 16A (13533), API RP-17G (ISO 13628-7) and draw attention to what is required for a subsea well intervention coiled tubing/wireline BOP rams. I will go through some of the qualifications that have been performed for some products, difficulties and challenges with certain sections and conclude with a summary.
We all want to be provide a safe environment during a well intervention project or campaign. The industry standards set guidelines for us to follow so that we have a reassurance that the equipment we put on our wellheads will keep everyone safe. We are challenged as the wells get higher pressure, higher temperature and deeper waters. The risk increases and any small accident could be catastrophic. We are therefore faced with challenges during well intervention operations, we must have confidence the equipment we are putting on our wells is sufficient, adequate and will work when we need it to work.
Performance Verification Testing is one of the major steps we take to ensure the equipment is fit for purpose. We perform a range of tests on the equipment to ensure that it will work when we need it to. Some equipment is used on a daily basis, other tools are used only during certain situations and then you have the tools that are used as the last step to contain the well.
The steps I am going to go through are the steps taken to qualify equipment for well intervention. I will go through the requirements for API 6A, 16A, and 17G and some challenges we have faced and conclude with some suggestions.
Merging Tapered in Coiled Tubing (CT) and Well Tractor Technologies to Effectively Stimulate Extended Reach Open Hole Horizontal Wells
Authors: AlDhufairi Mubarak , AlGhamdi Saleh , Noya Vidal , Al-Aradi Khaled , Al-Sarakbi Samer , Al-Dossary Ahmed , Krueger E. , Moore B. 
Published: July 2010

Abstract
The M field development involves one of the largest drilling projects in Saudi Arabia, targeting various carbonate reservoirs, and with an extraordinary amount of extended reach wells (ERWs) requires meeting the expected oil production rate, at the lowest development cost possible. More than two-thirds of the wells fall under the extended reach drilling classification, and the majority of the wells have measured depths (MDs) between 24,000 ft and 31,000 ft. These wells are open hole completions where acid stimulation is highly needed to overcome reservoir damage and improve the well's performance after drilling operations terminate.
The placement of the treatment fluids requires a uniform distribution along the open hole section. Among the different techniques considered, namely bullheading, using the rig drill pipe and coiled tubing (CT), the last one offered the soundest technical and cost option. However, the CT technique alone did not show the ability in reaching the maximum depth in most ERWs of this field. Therefore, the tractor1 was required to provide the significant amount of pull force needed to operate inside these long distances, not seen before in open hole completions.
The first eight well campaigns, using a combination of CT, a hydraulic tractor and friction reducer fluids, have achieved the main objectives. Moreover, a new intervention world record2 was set when the CT bottom-hole assembly (BHA) reached the maximum depth of 28,257 ft inside open hole in two different occasions, to place the stimulation fluids, and to record an injection profile. During the campaign, a total of 41,774 ft accumulated footage has been operated with the tractor, allowing over 3,400 bbls of acid to be placed in direct contact with the formation. As a result, the average injection rate has increased more than tenfold, reducing the drilling requirements for injection wells originally projected.
The job preparation, technology, results, learning curve experience and best practices are discussed in this paper, including proposed operational enhancements. This experience demonstrates the feasibility of the operations with CT required for full zone coverage, yielding optimum water injection rates at the lowest development cost.