bluuebunny/crossref_metadata_2025_split huggingface dataset:
A Solution to Instability Problems in Continuous Gas-Lift Wells Offshore Lake Maracaibo
Authors: Faustinelli Juan , Bermúdez Gastón , Cuauro Antonio 
Published: December 2007

Abstract
Unstable flow condition is a limitation for production optimization in continuous gas-lift wells due to casing and tubing heading. The instability could be caused due to insufficient gas injection volume, incorrect port diameter size, and variation of gas-lift injection rate due to subcritical flow condition at the point of operation. The traditional square-edge orifice valve is a cylindrical channel used to transport the gas. To reach critical flow condition, the downstream pressure has to be 50% to 40% the upstream pressure, and cannot be used to eliminate instability due to the excessive pressure differential required to achieve this flow regime. Therefore, a new valve was developed, which has the advantage to reach sonic flow velocity when pressure differential is only 10%, due to its converging diverging flow geometry. Comparing the dynamic flow performance of both square-edge and Nova valve, the Nova is independent of the downstream pressure and ideal as means of eliminating upstream instability.
Around 4200 wells currently operates under continuous gas-lift in Lake Maracaibo and 5% to 10% of these operates at unstable flow conditions due to subsonic flow at the injection point. For this reason PDVSA E&P decided to carry out field tests using a new gas-lift stabilization valve called Nova or nozzle-Venturi valve in wells with emulsion problems, high water content or low differential pressure across the operating valve which causes casing and tubing heading. There were installed 7 Nova valves in wells with crude oil gravity ranging from 14° API to 30° API, producing from 300 blpd to 2000 blpd, gas injection volumes of 500 Mscfd to 2000 Mscfd, and as deep as 12000 feet.
The well test results indicate that this new technology could stabilize the gas injection volume eliminating the casing heading and minimizing fluctuations of the tubing pressures. The potential application of this new valve in Lake Maracaibo oscillates between 300 to 400 wells. It is the scope of this work to present the selection criteria used to choose the well candidates, the results and experience gained during the field tests.
Probe Testing of Gas Lift Valves for Effective Performance Prediction and Better Gas Lift Design
Authors: Adiyodi K. S. , Kumar R. Sujith , Singh Rajiv 
Published: December 2007

Abstract
Optimum production from a gas lift well mainly depends on proper injection gas quantity, injection pressure and depth of injection. The quality of down hole gas lift valves plays a crucial role in achieving maximum efficiency of a gas lift system and un interrupted oil and gas production . This study carried out by probe testing and dynamic testing enable us to analyse the characteristics of the Bellows, termed as the heart of a gaslift valve, to predict various flow regimes, to design a gaslift system more accurately and proper monitoring of gaslift operation. The paper deals with Experimental Lab study and detailed analysis of approximately 200 probe tests and dynamic tests carried out on GLVs of different manufacturers.
Run Life Enlargement Methodology for Ball-and-Seat Check Valves Used in Artificial Lift Pumping Units
Authors: Zarea S. , Rojas-Solorzano L. , Kabboul F. 
Published: December 2007

Abstract
Experiments are performed to evaluate the leakage vs. pressure drop, wear and fluid properties, in ball-and-seat valves used in pumping units for artificial oil production. The test facility is constructed to evaluate the operation of several valve sizes, using water, oil and air, subjected to pressure drops up to 5000 psig. Results demonstrated that the currently accepted API vacuum test might be too severe and that more realistic tests may lead to substantial savings in valve replacements. Experimental results in dimensional and dimensionless form are presented, using a new similitude criterion.
Time-Critical Decision Making Using PC-Based Reservoir Simulation
Authors: Hazlett W. G. , Buchwalter J. L. , Calvert R. E. , Campbell T. M. , Molohon R. A. 
Published: December 2007

Abstract
Reservoir simulation has typically been applied to only the larger and more complicated reservoirs. The cost of performing such studies in a Unix/Workstation environment is high and most fields are not analyzed using reservoir simulation. High-power inexpensive PCs, and software with a powerful, user-friendly interface that does not require a simulation expert has changed the economics of performing such studies to such an extent that engineers and geologists are now using PC-based reservoir simulation to evaluate exploration plays on a real-time basis. This paper documents the process and results of a study that involved mapping, gridding, geostatistics and reservoir simulation of an exploration prospect while the drilling rig was on-site. The paper demonstrates the feasibility of using PC-based reservoir simulation as a routine part of reservoir management, beginning with the exploration well.
Lagomar's Integrated Field Laboratory for Intensive Evaluation of Technologies
Authors: de Carvajal G. , Velasquez A. , Graterol J. , Ramirez F. , Medina M. , Guimerans R. 
Published: December 2007

Abstract
PDVSA's light oilfields in Lake Maracaibo have been under exploitation for more than four decades. To date, the expected recovery factor is only 29% of the OOIP. As these resources approach maturity, it has been realized that improving recovery will demand the earliest use of many technologies, proven and new, in an integrated manner and tailored to solve specific regional problems. The Integrated Field Laboratory (IFL) philosophy is one of PDVSA's main technology strategies designed to accomplish these goals. Three Field Laboratories are being developed in the Maracaibo Lake Basin: one for heavy oils and two for light oils: shallow and deep reservoirs.
The VLA-6/9/21 area in Lagomar Field was selected to evaluate technologies with potential application to highly depleted, medium to light oil reservoirs, which are either under or have favorable conditions for waterflooding and at depths bellow 10000 feet. Venezuela has over 30000 MMSTB of oil currently in place in reservoirs with similar conditions. This huge volume of oil provides the incentive to conduct the work described in this paper.
The engineering management approach for technology evaluation being used is comprised of: 1)Advanced reservoir characterization, simulation and visualization, 2)Drainage strategies, including displacement processes and well architectures, 3)Well construction at minimum time, damage and cost, 4)Technologies to improve injectivity/productivity, 5)Advanced monitoring technologies aiming to intelligent reservoirs, 6)Technologies for handling produced and injected fluids and 7)Techniques to evaluate and quantify risk.
Multidiscisplinary multiparticipant virtual work teams have been structured in order to execute this project. These teams are being integrated with specialists from different disciplines within PDVSA, such as: Technology Department, Exploitation Units and Research Institute (Intevep), national and international universities, service companies, national and international consultants, etc.
This paper describes the main aspects of the design of Lagomar's Field Laboratory, the results obtained during the first year of operations, and the future plans. Some of the technologies currently under evaluation are: 1)High resolution reservoir characterization, simulation and visualization, 2)Well to well seismic, 3)Fluids for at balance drilling, 4)Foam cements, 5)Multiwell injectors, 6)Commingle production, 7)Massive fracturing and 8)Down-hole sensors.
Successful Pilot of Thermosyphon Process Heater Reduces GHG Emissions and Operating Costs
Authors: Arnold W. A. , Neulander J. I. 
Published: December 2007

Abstract
PanCanadian originally pursued thermosyphon technology to lower operating costs. However, it is now apparent that a more significant benefit is reduction of greenhouse gas (GHG) emissions. Other benefits include loss management, increased safety, improved operability and maintenance cost reduction.
A prototype Thermflo™ thermosyphon process heater was developed by Hudson Products Corporation (HPC) as a joint effort with PanCanadian Petroleum Ltd. The unit was installed in a 320 m3 atmospheric heavy oil tank in northeastern Alberta in November '97. Performance testing was carried out over the next several months and evaluated using API Standards & Recommended Practices.
The testing was carried out in two phases. In phase one, we compared the performance of the thermosyphon to a naturally drafted venturi style nozzle burner in a firetube located in an adjacent tank. Both units were fired using sales utility gas. Increased combustion efficiency and improved heat transfer reduced fuel gas consumption by 33% and cut GHG emissions by 40%. In phase two of the testing, the prototype successfully burned solution gas normally vented to atmosphere. This translates to an annual operating cost saving of about $40,000 and GHG emission reduction of about 10,000 tonnes per year.
Frac and Pack Completion Strategy in Duri Steam Flood (DSF) Field PT Caltex Pacific Indonesia
Authors: Satyagraha Mathias T. , Aimar Amritzar 
Published: December 2007

Abstract
Frac and Pack was introduced to Duri Steam Flood (DSF) in 1996 and has become the preferred completion technique. Frac and Pack combines the stimulation advantages of hydraulic fracturing with the sand control benefits of Gravel Packing.
Frac and Pack treatment was first used in Area 4 Rindu Vertical Expansion (RVE) Project. These wells were recompleted with a Frac and Pack completion into a shallower producing zone (Rindu Sand). Now Frac and Pack completion is used in almost all new and recompletion wells in DSF.
Frac and Pack treatment combines fracturing and gravel packing into one step with a liner in place. The Tip Screen Out (TSO) design technique is used to ensure that proper fracture width and proppant concentration are adequate to effectively connect the reservoir to the wellbore. The Frac and Pack job is finished with an annular sand pack between the wire wrapped screen and the cased hole.
This paper will share success story, best practices, lessons learned, and techniques in Frac and Pack completion. Opportunities for job cost reductions will also be shared. In addition, a comparison of Frac and Pack and Gravel Packs will be discussed.
In summary, Frac and Pack completion has proven to be very effective in DSF and can be used in other fields to increase well productivity and sand control performance.

History
Fracturing in DSF first began in the Rindu Pilot Project. The pilot test on fracturing technology was successfully performed on four cased hole wells in the Rindu Pilot area during December 1995 and January 1996. For the first time a screenless completion was used to complete the Rindu formation in DSF. This completion consisted of a tip screen out (TSO) fracture, using Curable Resin Coated (CRC) sand. This treatment was performed without gravel packed screen in the well.
A study of TSO's in A4-RVE found that a lot of wells experienced sanding problems. There may be multiple reasons for the failure of the CRC and the TSO Frac to control sanding. For instance, not all perforations received CRC sand during placement, steam from surface did not reach and cure CRC in the entire section, and non-CRC sand had already bridged over some of the perforations before or during treatment1.
From the result above, CPI tried Frac and Pack (FP) completion. FP was first tried in Area 4-RVE Project. These wells were recompleted with FP completion into a shallower producing zone (Rindu Sand). Now, FP completion applies in almost all new and recompletion wells and has become the preferred completion method in sand control environments in DSF.
Application of Honeycomb Welded Structures to Petroleum Engineering Facilities
Authors: Okuto K. , Fujita K. 
Published: December 2007

Abstract
Honeycomb welded structures were first introduced to the 5th INALCO ‘92 and further developed into some application stages since that time. A successful stage is marked by the use of honeycomb panels to the coach shell of a hundred sixty Shinkansen bullet train bodies which are running in commercial operation begun at the end of 1998. Another application is found in roofing members of several architectural building structures in Japan. Manufacturing procedures of honeycomb and sandwiched panels by welding are also developed and introduced ever since.
Because aluminum or steel panels thus manufactured are weldable, the structures fabricated and erected are termed as "Honeycomb Welded Structures". Further studies have been carried out, finding some more applications in the petroleum related fields of industry. An example in the paper is light-in-weight but strong and rigid enough roof for oil storage tanks. Further uses are considered to the various structural members for top-side facilities in production-, accommodation- and drilling-offshore platforms, and even in drilling rigs.
The paper specifically emphasizes the superior characteristics of honeycomb welded structures, inevitably related to the rigidity, strength, fabrication and construction capabilities. Design procedures are reviewed briefly, and a conceptual design for oil tank roof is discussed in detail. In addition, fabrication and erection examples are illustrated, for the sake of better comprehension of honeycomb welded structures.
First Diverless Subsea Wireline Well Intervention Performed in Offshore Vietnam offers Low-Cost Solution for Light Well Workovers: Case Histories and Future Trends
Authors: Larimore David , Ashwell Charles , Abidin Abdul Halim Zainal 
Published: December 2007

Abstract
Subsea completions have been on the rise in recent years due to the economics, extreme environments, the use of infrastructures (subsea tiebacks), and migration to water depths in excess of 1300-feet. In this paper, subsea slickline operations are performed on three cluster wells situated beneath the operator's semi-submersible floating production unit in Vietnam's offshore Dai Hung field. The services were needed for reservoir management, including installation and retrieval of memory gauges, performance of logging surveys, and to manipulate sliding sleeves that had been installed with the ultimate purpose of optimizing hydrocarbon recovery. A subsea wireline unit (capable of deploying slickline and electric line) was chosen to provide the services. This unit was selected because of its cost efficiency and capability to perform a fishing job without impacting platform space and weight restrictions on the floating production unit as would have been imposed by use of a drilling riser. This paper will provide the case history of these services, which were unique in that these were the first diverless subsea slickline jobs performed solely with remote-operated vehicle (ROV) support for manipulation or assistance. Slickline provided an effective solution for the operator's service requirement within the specified criteria. Because of the versatility of newly developed advanced systems, slickline equipment was able to meet the restrictions of weight and size on platforms to provide a more efficient alternative for services that traditionally require rig mobilization.
As a result of the success of this operation, the operator is planning other subsea slickline services that will be performed without a drilling or jack-up rig.
With the present economic climate of the oil-and-gas industry, the significant costs normally associated with heavy workover and drilling facilities have strengthened the need to find other ways to enhance cost efficiency in subsea workover scenarios. To support this trend, innovative methods that have expanded the scope of operations that can be performed on subsea wells without a drilling rig have now been introduced. As an example, plug and abandonment operations can be performed with subsea wireline intervention units and other coiled tubing and wireline intervention techniques rather than with a tensioned riser from an anchored drilling vessel or a jack-up rig. With the new methods, the deployment system for wireline and coiled tubing does not require special system modification—any standard wireline or coiled tubing unit can be used. These techniques will be discussed more fully in the paper.
Nuclear Magnetic Resonance and Carbon/Oxygen Logging Improve Determination of Residual Oil Saturation: A Case Study from the Minas Field
Authors: Eyvazzadeh Ramsin Y. , Nguyen Chuong , Fox Phil , Peornomo Bambang 
Published: December 2007

Abstract
The effect of pore-fluid diffusion on nuclear magnetic resonance (NMR) measurements is now being used to quantitatively determine oil saturation in subsurface formations. This new NMR application is helping improve interpretation models for carbon/oxygen (C/O) measurements.
This paper discusses the petrophysical advantage of combining the very different NMR and C/O measurements to better define near-borehole oil saturation. The Minas Field in central Sumatra has been logged extensively with C/O and NMR tools and provides a case study that exemplifies the new logging and data-interpretation methodology.
Coiled Tubing Milling and Temporary Plug and Abandonment Operations
Authors: Sørgård Eirik , Østvik Egil , Grønnerød Njål , Svanes Grete , Villar John , Salvesen Tom , Tjåland Lars 
Published: December 2007

Abstract
In order to establish barriers to enable a safe removal of a sub sea BOP, two temporary cement plugs had to be placed in the 10¾″ casing using 2″ coiled tubing (CT).
The operation was performed from a floating drilling/production semi submersible rig in 360 m water depth connected to the well by a marine riser.
A 23/8″ hole was milled through a BOP testing tool assembly (BTT), which had become stuck below the BOP due to a malfunction of a BOP ram, while containing well control throughout the operation.
A novel OBM formulation design was utilized in order to clean up the settled solids in the OBM in the well through the 23/8″ milled hole.
A novel cement packer was run down to 2000 m through the 23/8″ milled hole and set in the 10¾″ casing, allowing a successful cement plug to be placed in a 46 degree inclination at extremely low pump rate utilizing coiled tubing. A similar cement plug was set and tested at 900 m using the same method.
The whole operation was completed successfully considering that a lot of uncharted coiled tubing technology was utilized.
Coiled Tubing String Longitudinal Properties
Authors: McCoy Terry , Avakov Vladimir , Rosine Randy , Martin John 
Published: December 2007

Abstract
This paper discusses test results of material properties along the length of a coiled tubing (CT) string that was manufactured in 1997. The 1.50-in. OD, 0.102-in. WT, 9,052-ft CT sting was made from 80-ksi yield strength material. The new string was manufactured with conventional procedures and was cut into 362 25-ft segments. The segments were properly numbered, protected against corrosion, and stacked. Among them, 128 segments were chosen for testing.
Samples from the test segments were prepared for fatigue testing and tensile testing. Fatigue testing was performed with a bending machine having a 48-in. bending arch and 4,000-psi internal pressure. Tensile testing was performed with full-body specimens to determine yield strength, ultimate tensile strength, modulus of elasticity, elongation, and reduction of area.
A total of 252 samples were tested. Test data are statistically analyzed, and their distributions along the length of length of the CT string are plotted. The results are compared with correspondent specifications and standards.
Application of C.T.D. Offshore, Indonesia Phase One Pilot Project
Authors: Kirk Andrew , Sembiring Taufiq 
Published: December 2007

Abstract
The trend of increasing jack up drilling rig rates in 1996 and the fact that Atlantic Richfield Indonesia Incorporated (A.R.I.I.) has many wells on tripod platforms are the primary factors for ARII to find an alternative way to drill sidetrack wells on tripod platforms. One possible solution is Coil Tubing Drilling (CTD). This paper is a case study of Arco Indonesia's 1997-98 CTD pilot project describing the operation of CTD on these platforms. The focus of this paper will be on; rig up of surface equipment, operational overview and lessons learned for future wells using CTD on tripod platform wells.
Downhole Video Optimizes Scale-Removal Program
Authors: Tague J. R. , Hollman G. F. , Chaffin G. 
Published: December 2007

Abstract
In fields with potential for scale buildup, downhole video offers a unique and cost effective method for obtaining direct visual data of scale in the wellbore environment. In a recent study, Chevron successfully used downhole video logging to obtain actual images of scale deposits in producing wells. These images were used to design and optimize a scale removal program in the West Coalinga field of Central California.
Simulation of Early-Time Response of Single-Well Steam Assisted Gravity Drainage (SW-SAGD)
Authors: Elliott K. T. , Kovscek A. R. 
Published: December 2007

Abstract
Steam assisted gravity drainage (SAGD) is an effective method of producing heavy oil and bitumen. In a typical SAGD approach, steam is injected into a horizontal well located directly above a horizontal producer. A steam chamber grows around the injection well and helps displace heated oil toward the production well. Single-well (SW) SAGD attempts to create a similar process using only one horizontal well. This may include steam injection from the toe of the horizontal well with production at the heel. Obvious advantages of SW-SAGD include cost savings and utility in relatively thin reservoirs. However, the process is technically challenging.
To improve early-time response of SW-SAGD, it is necessary to heat the near-wellbore area to reduce oil viscosity and allow gravity drainage to take place. Since project economics are sensitive to early production response, we are interested in optimizing the start-up procedure.
An investigation of early-time processes to improve reservoir heating will be discussed. We performed a numerical simulation study of combinations of cyclic steam injection and steam circulation prior to SAGD in an effort to better understand and improve early-time response. Results from this study, including cumulative recoveries, temperature distributions, and production rates display variances within the methods. It is found that cycling steaming of the reservoir prior to SAGD offers the most favorable option for heating the near-wellbore area and creating conditions that will improve initial SAGD response.
Flexible, Real-Time Tip-Screenout Fracturing Techniques as Applied in California and Alaska
Authors: Upchurch E. R. 
Published: December 2007

Abstract
This paper discusses the application of two variations on a flexible tip screenout (TSO) technique that allows for realtime changes of fracture treatments to compensate for uncertainty in fluid leakoff and fracture geometry. The basic premise for each technique is the same; that is, change frac job size as necessary during the job to attain a TSO using realtime data. The techniques differ, however, because of physical system constraints, which result in different types of data being available to make real-time decisions. In the West Sak Field of Alaska, real-time bottom-hole pressure is available for decision making purposes (a best-case scenario). In the East Wilmington Field of California, real-time bottom-hole pressure is not available; thus, the flexible TSO technique is implemented differently to yield the best possible flexibility under these less-than-optimal data conditions.