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Collaborating Authors
Pressure Management
Unique Process and Tool Provides Better Acid Stimulation and Better Production Results
Al-Saqabi, Mishari (Kuwait Oil Company) | Gazi, Naz (Kuwait Oil Company) | Vishwanath, Chimmalgi (Kuwait Oil Company) | Al Bahrani, Hasan (Kuwait Oil Company) | Turkey, Naween (Kuwait Oil Company) | Abdul-Razaq, Eman (Kuwait Oil Company) | Al-Zankawi, Omran (Kuwait Oil Company) | Bouland, Ali (Kuwait Oil Company) | Surjaatmadja, Jim B. (Halliburton) | Al Hamad, Abdulla M. (Halliburton) | Brand, Shannon (Halliburton)
Abstract There are many ways to stimulate an unlined openhole horizontal well using acid. The simplest way is to just pump acid into the well (i.e., bullhead) without placement control. However, this can often be ineffective. Although still used, such approaches can create massive enlargements at the entry point or high injectivity area, thus causing ineffective treatments and re-entry issues. Wellbore collapse often follows. The use of coiled tubing (CT) as a "pin-point" delivery method is therefore preferred. Using CT allows dispersal of the acid either uniformly or intermittently along the lateral, as desired. CT also allows acid washing to be performed, which is another common process that can improve stimulation without much additional expense to the operator. Using a jetting tool with many jets, acid can be sprayed onto the wellbore wall, and the active agitation caused by the acid-wash process increases the chemical reactivity of the acid at the desired locations. Another beneficial approach of using CT is the hydrajet assisted acid fracturing (HJAAF) method. With focused jetting of acid at much higher pressures, the process initiates microfractures in the wellbore walls. When etched with acid, this approach effectively bypasses near-wellbore (NWB) damage much deeper than common washes, thus providing much better results. Further modification of the process by exerting high annular pressures offers the capability of delivering medium to large fractures. This paper discusses two HJAAF processes uniquely combined into one process used in two large horizontal wells. Because of the large dimension of the inner diameter (ID) of the wells combined with the small production tubing the tool must pass through, the implementation had to be further improved by using a unique jetting mechanism, which positioned the jet nozzles closer to the target. Actual results of such stimulations are presented.
- North America > United States (0.94)
- Asia > Middle East > Kuwait (0.30)
First Application of Extended Range Electromagnetic MWD Technology in Pakistan for a Horizontal Well Drilled Underbalanced-Case Study and Lesson Learned
Saleem, Saad (1Pakistan Petroleum Limited) | Sattar, Muhammad Suhail (1Pakistan Petroleum Limited) | Shahzad, Atif (2Weatherford Oil Tools M.E. Limited, Pakistan) | Ziadat, Wael (2Weatherford Oil Tools M.E. Limited, Pakistan) | Sabir, Shahid Majeed (2Weatherford Oil Tools M.E. Limited, Pakistan)
Abstract The name "Sui" has become synonymous with natural gas in Pakistan. Sui is Pakistan Petroleum Limited's (PPL) flagship gas field. Commercial exploitation of this field began in 1955. Two major reservoirs of this field are Sui Main Limestone (SML) and Sui Upper Limestone (SUL). Both the reservoirs have become highly depleted by time. Conventional drilling technologies in these formations result in complete loss of drilling fluid, stuck pipe and severe formation damage issues. Pakistan Petroleum Limited (PPL) planned to drill a horizontal well Sui-93(M), where target reservoir was Sui Main Limestone (SML). Drilling a horizontal well with conventional drilling techniques can cause a complete loss of drilling fluid. Underbalanced Drilling integrated with electromagnetic telemetry transmission was successfully used to drill this well to a target depth of 2200m MD with complete directional controls. Electromagnetic transmission modeling was performed on the resistivity data of offset wells to determine signal attenuation for Sui-93(M) Well. Based on modeling results it was decided to run an extended range set-up with a downhole antenna. The main reason for using EM-MWD was to provide real time data for annular pressure (APWD sensor) and directional controls in UBD environment. The APWD (annular pressure while drilling-real time ECD) sensor was considered mandatory to monitor and ensure underbalanced condition while drilling, thereby avoiding significant problems such as lost circulation and stuck pipe. This paper discusses the planning, results, problems and lessons learned during the first application of the Extended Range EM-MWD (Electromagnetic-Measurement while drilling) technology in Sui-93(M) well. The application of EM-MWD along with UB technology represents a stepwise progression for improving PPL's ability to exploit mature reservoirs, especially those that are severely depleted like in Sui Gas Field, Pakistan.
- Asia > Pakistan > Sindh > Central Gas Basin > Sui Main Limestone Formation (0.99)
- Asia > Pakistan > Balochistan > Dera Bugti District > Lower Indus Basin > Guddu Block > Sui Field (0.99)
- Well Drilling > Pressure Management > Underbalanced drilling (1.00)
- Well Drilling > Drilling Operations (1.00)
- Well Drilling > Drilling Measurement, Data Acquisition and Automation > Measurement while drilling (1.00)
- Data Science & Engineering Analytics > Information Management and Systems (1.00)
Oil and gas operations are moving to more complex deepwater and onshore unconventional projects, and activity in the industry is higher than ever before. Meanwhile, brownfield projects for increased reservoir recovery are also changing industry parameters. Arctic and ultradeepwater exploration has created a new learning curve in the industry, while advances in technologies and techniques have opened up new areas of exploration and production for business. Discussion of these topics will take place at the 2013 SPE/IADC Drilling Conference on 5–7 March at the Rai Congress Centre in Amsterdam, Netherlands. Exploration and development are moving to deeper waters, more remote and sensitive environments, higher pressure formations, and sour reservoirs.
- Europe > Norway (0.51)
- Europe > Netherlands > North Holland > Amsterdam (0.25)
- North America > United States > Texas (0.16)
- Asia > Middle East > Saudi Arabia (0.16)
- Reservoir Description and Dynamics (1.00)
- Well Drilling > Drilling Operations > Directional drilling (0.54)
- Well Drilling > Pressure Management > Well control (0.51)
Abstract It is fundamental to pilot and deploy IOR/EOR initiatives to improve recovery from petroleum reservoirs using cost effective methods, ensuring a continuous supply of production that would meet the ever-increasing demand for energy. Under-Balanced Drilling (UBD) technology proved worthy as a valuable initiative in the redevelopment strategy of a Giant Carbonate reservoir located in the Middle East. It improved well deliverability especially in low permeability reservoir zones. The strategy for this has been to deploy 3-4000 feet laterals to maximize reservoir contact to such tight units or drill as far as possible to have maximum flow input/productivity. Horizontalization (non-UBD), together with stimulation has been going on for many years with mixed success as recent production log surveys showed negligible contribution from several wells completed in these low permeability units. In 2011, well-X was drilled underbalanced to assess the value of this technology in augmenting productivity and improving reservoir characterization. Significant improvement in Productivity Index was accomplished by minimizing damage from drilling and completion operations. In addition, considerable knowledge was acquired from Flowing While Drilling (FWD) data and multi-rate tests in four segments of the production zone. Real-time geosteering was actively used to account for changes in the reservoir architecture. Analysis of the FWD data has derived in new understanding of the dynamic nature of the reservoir's South-central region, highlighting sectors of high permeability, fractures, tight areas, different pressure regimes and varying fluid composition. Furthermore, despite the innovative nature of the technology, drilling and completion was very well controlled by the Well Construction teams, resulting in costs not significantly higher than normal over-balanced wells. The enhanced reservoir knowledge that UBD delivers as shown from well-X will result in improved recovery efficiency and possible delayed water production. Moreover, it is a lead value improvement technology that will meet strategic business objectives with minimum risk and lowest Unit Technical Cost.
- Asia > Middle East (0.88)
- Europe (0.88)
- North America > United States > Texas (0.68)
- North America > United States > Texas > Permian Basin > Yeso Formation (0.99)
- North America > United States > Texas > Permian Basin > Yates Formation (0.99)
- North America > United States > Texas > Permian Basin > Wolfcamp Formation (0.99)
- (21 more...)
- Well Drilling > Pressure Management (1.00)
- Well Drilling > Drilling Operations (1.00)
- Well Completion > Completion Installation and Operations (1.00)
- (6 more...)
Technology Focus It has been a busy year for me; I definitely played less golf. I was appointed as the deputy chief of commercialization in the University of Malaya Center of Innovation and Commercialization (UMCIC) about a year ago. My tenure has just been extended for another year. UMCIC is a special unit within the university that spurs and elevates innovation and commercialization of academic research activities and output. This is echoed in most innovation and commercialization seminars and workshops. Everyone is talking about “the valley of death” and the challenges of getting universities and industry to be on the same page. In a recent oil and gas workshop I attended, a participant highlighted the limited (or lack of) real field-scale trials in the area of nano-technology application. It is an open secret that many industrial players tend to play it safe. As they say, “If it is working, don’t fix it.” However, things have changed over the years. The increases in energy demand and limited resources have driven the industry players to explore novel technologies, one of which is exploration and production nanotechnology. A tremendous amount of money has been invested in research laboratory and field trials in this area. In this feature, I highlighted four interesting papers that cover theoretical and experimental approaches and real field tests related to nanotechnology. The selected papers primarily discuss the applications of nanotechnology, specifically in drilling fluid technology. Two of the selected papers discuss field tests. One of the papers presents interesting preliminary test results of nano-based drilling fluids. It describes the formulation and test results of several nano-based fluids. The last paper presents the industry’s first field trial of a reservoir nanoagent. Here, the first industrially proven reservoir nanoagent template has been introduced and demonstrated through a push/pull field trial in an observation well. Another thing I learned, from a commercialization workshop, was the importance of commercializing an innovation. Innovation without commercialization is like watching a major golf tournament on Sunday without Tiger Woods, Rory McIlroy, Phil Michelson, Sergio Garcia, Jim Furyk, Matt Kuchar, Nick Watney, Steve Stricker, Zack Johnson, Jason Dufner, or Lee Westwood making the cut. I hope you enjoy and benefit from the selected papers. Don’t forget to look at the other interesting papers on the recommended reading list. In addition, watch for other related papers in the OnePetro online library. Recommended additional reading at OnePetro: www.onepetro.org. IPTC 14952 An Experimental Investigation on Use of Nanoparticles as Fluid Loss Additives in a Surfactant/Polymer-Based Drilling Fluid by Jayanth T. Srivatsa, Texas Tech University, et al. SPE 140816 A Biodegradable Chelating Agent Designed To Be an Environmentally Friendly Filter-Cake Breaker by Natalia Collins, Halliburton, et al. SPE 145840 Mitigating Lost Circulation and Differential Sticking Problems Using Silicon Nanoparticles by Saket M. Javeri, Maharashtra Institute of Technology, et al. SPE 153729 Wellbore Stability in Unconventional Shale—The Design of a Nanoparticle Fluid by Meghan Riley, M-I SWACO, et al.
- North America > United States > Texas (0.26)
- Asia > India > Maharashtra (0.26)
- Well Drilling > Drilling Fluids and Materials > Drilling fluid selection and formulation (chemistry, properties) (0.92)
- Well Completion > Completion Fluids > Completion fluids (0.89)
- Well Drilling > Drilling Fluids and Materials > Drilling fluid management & disposal (0.72)
- Well Drilling > Pressure Management > Well control (0.57)
Abstract Foam-assisted underbalanced drilling technique is advantageous over the traditional overbalanced drilling near the productive water-sensitive formations due to its reduced formation damage, improved rate of penetration, higher cutting-transport capacity, and lower circulation losses. However, the complicated nature of foam rheology has been a major impediment to the optimal design of field applications. Earlier studies with surfactant foams without oils and polymers show that foam flow in pipe can be represented by two different flow regimes: the low-quality regime showing either plug-flow or segregated-flow pattern, and the high-quality regime showing slug-flow pattern. The objective of this study is to investigate foam flow characteristics in horizontal pipes at different injection conditions, with or without oils, by using polymer-free and polymer-added surfactant foams. The results of this study were presented in two different ways: (i) steady-state pressure drops (or, apparent foam viscosity, equivalently) measured by multiple pressure taps and (ii) visualization of bubble size, size distribution and flow patterns in transparent pipes. The results with surfactant foams and oil showed that (i) oil reduced the stability of foams in pipes, hence, decreasing the steady-state pressure drops and foam viscosities, and (ii) the presence of oil tended to lower the transition between the high-quality and the low-quality regimes (i.e., lower foam quality at the boundary, or lower fg* equivalently). In addition, the results with surfactant foams with polymer showed that (i) polymer thickened the liquid phase and, if enough agitation was supplied, could make foams long-lived and improve foam viscosities, and (ii) the system sometimes did not reach the steady state readily, showing systematic oscillations. In both cases, though, the experiments carried out in this study showed the presence of two distinct high-quality and low-quality flow regimes.
- Europe (0.68)
- North America > United States > California (0.46)
- North America > Canada > Alberta (0.28)
- Well Drilling > Pressure Management > Underbalanced drilling (1.00)
- Reservoir Description and Dynamics > Improved and Enhanced Recovery > Chemical flooding methods (1.00)
- Production and Well Operations > Well & Reservoir Surveillance and Monitoring > Production logging (1.00)
Abstract Mitigating down time, while curing losses, is a critical part of designing and executing a good well plan. Even when anticipated, the loss of drilling fluids to depleted formations is a costly event resulting in excessive down time for the entire rig as well additional costs in replacing costly drilling fluids. The search for new hydrocarbon reserves increasingly sends us back to proven fields where drilling through depleted zones as become an increasing liability to daily operations. The costly time required to pump multiple activation and deactivation balls down the string makes operating conventional tools tedious and time consuming. A more efficient tool for the placement of lost circulation materials (LCM) that does not require the exorbitant lost time and complicated cycling methods of the current technology has not been available for over a decade. Today, a new tool, utilizing innovative shifting technology, provides unlimited open / close cycles. With this technology, drillers can shift an unlimited number of times and in as little as 5% of the time required by conventional tools. These capabilities result in direct reduction of lost time operating the tool as well as a quantifiable reduction in fluids lost while operating the tool. Simplified operation also makes the tool uniquely easy to operate reducing the potential for user errors that frequently plague existing technology. This paper details how the use of this innovative circulating technology has assisted a major service company in reducing downtime and excessive costs during lost circulation events. The design has proven simpler to operate and has effectively reduced the non-productive time and lost fluid versus operation of conventional circulating subs. Supporting case studies are included to detail the increase in efficiency and reduction in costs.
- North America > United States (1.00)
- Europe > Norway > Norwegian Sea (0.25)
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > North America Government > United States Government (0.46)
- Well Drilling > Pressure Management > Well control (1.00)
- Well Drilling > Drilling Fluids and Materials > Drilling fluid management & disposal (1.00)
Copyright 2012, Society of Petroleum Engineers This paper was prepared for presentation at the SPE Russian Oil & Gas Exploration & Production Technical Conference and Exhibition held in Moscow, Russia, 16-18 October 2012. This paper was selected for presentation by an SPE program committee following review of information contained in an abstract submitted by the author(s). Contents of the paper have not been reviewed by the Society of Petroleum Engineers and are subject to correction by the author(s). The material does not necessarily reflect any position of the Society of Petroleum Engineers, its officers, or members. Electronic reproduction, distribution, or storage of any part of this paper without the written consent of the Society of Petroleum Engineers is prohibited. Permission to reproduce in print is restricted to an abstract of not more than 300 words; illustrations may not be copied. The abstract must contain conspicuous acknowledgment of SPE copyright. Abstract The Verkhnechonskoye (VCNG) oilfield located in Eastern Siberia is developed on pad clusters, with in excess of 200 wells drilled to date. Typical well geometry consists of a vertical 13 3/8in. Production hole is drilled in 6in. The predominant well design incorporates a double build profile which lands horizontally in the Verknechonskiy reservoir with an approximate 600m lateral drilled in the productive zone. VCNG field has evolved of key strategic importance to deliver oil through the Eastern Siberia Pacific Ocean (ESPO) pipeline from Russia to the vast Asia-Pacific market located to its South East. Increasing production targets have been required to deliver hydrocarbons to fulfill aggressive pipeline commitments. Meeting these requirements have in turn initiated a relentless drive to enhance operational efficiency since the inception of development drilling phase in 2007; leading to a significant increase in drilling performance and reduction in overall well construction time in the period to date. This improvement has been achieved against the backdrop of an environment which is extremely challenging on several distinct fronts; remoteness of the project with 600km from the nearest major conurbation, harshness of an extreme continental climate with temperatures seasonally dropping to -50ºC and coupled with a unique and problematic lithological column all serve to make drilling, logistics and general operations a complex undertaking. The purpose of this paper will be to take a holistic review of drilling performance in the field and to chronicle the numerous incremental technological and procedural advancements which have led to a reduction in average well construction time from 58 to 21 days between 2007 and 2011.
- Asia > Russia > Siberian Federal District (0.28)
- Europe > Russia > Central Federal District > Moscow Oblast > Moscow (0.24)
- Geology > Geological Subdiscipline > Geomechanics (0.68)
- Geology > Rock Type > Sedimentary Rock (0.46)
- Well Drilling > Wellbore Design > Wellbore integrity (1.00)
- Well Drilling > Well Planning > Trajectory design (1.00)
- Well Drilling > Drillstring Design > Drill pipe selection (1.00)
- (9 more...)
Abstract Lost circulation caused by low fracture gradients is the cause of many drilling related problems. Typically the operational practice when lost circulation occurs is to add loss circulation materials (LCM) to stop mud from flowing into the formations. To improve the treatment for lost circulation caused by low fracture gradients, especially designed materials in mud system are used to seal the induced fractures around the wellbore. This operation is in the literature referred to as wellbore strengthening that has been found to be a very effective in cutting Non-Productive Time (NPT) when drilling deep offshore wells. Size, type and geometry of sealing materials are debating issues when different techniques are applied. Also the phenomenon is not truly understood when these techniques applied in different sedimentary basins. This paper presents development and simulation results of a three-dimensional Finite-Element Model (FEM) for investigating wellbore strengthening mechanism. This study also describes a procedure for designing Particle Size Distribution (PSD) in field applications. To better understand the numerical results, the paper also reviews the connection between Leak of Tests (LOTs) and wellbore hoop stress and how these LOTs can mislead in fracture gradient determination. A comprehensive field database was collected from different sedimentary basins for this study. Results demonstrate that the maximum attainable wellbore pressure achieved by wellbore strengthening is strongly controlled by stress anisotropy. Results also show that Particle Size Distribution (PSD) of wellbore strengthening should be designed in order to seal the fractures close to the mouth and at fracture tip. This will result both in maximizing hoop stress restoration and tip-screening effects. In addition this model is able to show the exact fracture geometry formed around the wellbore that will help to optimize the sealing materials design in wellbore strengthening pills. To support numerical modeling results, near wellbore fracture lab experiments on Sandstone and Dolomite samples were also presented. Laboratory experiments results reveal importance of rock permeability, tensile strength and fluid leak-off in wellbore strengthening applications.
- North America > United States > Texas (0.46)
- North America > United States > California (0.28)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock (0.51)
- North America > United States > Texas > Sabine Uplift > Trawick Field (0.99)
- North America > United States > New Mexico > San Juan Basin > San Juan Basin Field > Mancos Formation (0.99)
- North America > United States > Colorado > San Juan Basin > San Juan Basin Field > Mancos Formation (0.99)
- Well Drilling > Wellbore Design > Wellbore integrity (1.00)
- Well Drilling > Pressure Management > Well control (1.00)
- Well Drilling > Drilling Fluids and Materials > Drilling fluid management & disposal (1.00)
- Well Completion > Hydraulic Fracturing (1.00)
Abstract The paper will consider the implementation of the Safety Case in the oil and gas industry in Australia, and internationally, post the Macondo and Montara incidents. The National Commission Report into the Deepwater Horizon / Macondo blowout stated: In their letter to Minister Ferguson on 22 March 2011, the NOPSA Board stated: The paper will examine these criticisms and consider how the industry could improve its process safety and risk management. The implementation of a Safety Case in the USA may only occur "in the typical rule-making process that takes up to two years" (Michael Bromwich, Director of BOEMRE). Knowledge, understanding and application of key aspects of process safety management and the preparation and implementation of the Safety Case process are not uniform. The paper will suggest how, in this context, the Safety Case can be applied to achieve the improved outcomes. The paper will draw from specific findings from the Macondo and Montara incidents. In particular, and of some concern, there are echoes and parallels of the Piper Alpha disaster in the performance of emergency systems on Deepwater Horizon. Inadequate application of hazardous area classification is a key issue which the paper will discuss in order to provide greater understanding. Whilst in Australia, issues of competency, consistency and quality arise with matters such as performance standards. The paper will discuss the need for an industry accepted standard for "performance standards" that goes beyond current regulatory guidelines. Overall, the paper will seek to propose a way forward for the industry in several practical areas.
- Oceania > Australia (1.00)
- North America > United States (1.00)
- Government > Regional Government > North America Government > United States Government (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- North America > United States > Gulf of Mexico > Central GOM > East Gulf Coast Tertiary Basin > Mississippi Canyon > Block 252 > Macondo Field > Macondo 252 Well (0.93)
- Oceania > Australia > Western Australia > Timor Sea > Bonaparte Basin > Vulcan Basin > PL AC/L8 > Montara Field (0.91)
- Oceania > Australia > Western Australia > Timor Sea > Bonaparte Basin > Vulcan Basin > PL AC/L7 > Montara Field (0.91)
- Well Drilling > Pressure Management > Well control (1.00)
- Health, Safety, Environment & Sustainability > Safety > Safety risk management (1.00)
- Health, Safety, Environment & Sustainability > Safety > Operational safety (1.00)
- (2 more...)