bluuebunny/crossref_metadata_2025_split huggingface dataset:
A Hydraulic Fracturing Application To Overcome a Near Wellbore Damage in a High Permeability Formation
Authors: Soedarsono G. , Shucart J.K. , Harding C.D. , Said R. 
Published: December 2007

Abstract
In contrast to the common use of a hydraulic fracturing treatment in low permeability formations, recent advances of these treatment have overcome the limitations of matrix acidizing treatments performed in high permeability formations common to Indonesia. Being gravel packed with 5 Darcy permeability formation, WIA-8 well showed lower than expected productivity after completion. Efforts to restore the well productivity using matrix acidizing treatments resulted in additional productivity impairment. Recently, the well was worked over and the formation was treated with a small volume, high concentration, propped fracture treatment which successfully rectified the impairment. This is believed to be the highest permeability formation ever hydraulically fractured. This paper will outline the methodology used to design and perform a hydraulic fracturing treatment in high permeability formations.

INTRODUCTION
Widuri field is 90 miles (145 kms) north of Jakarta in the Java sea. The field is located on the northwest flank of the newly developed Asri basin (Figure 1).
The field was discovered in April 1988 vkaen Widuri-1 well was drilled to a total depth of 3735' subsea and encountered 170' of net oil pay in the Talang Akar sandstone formation. The field structure is a faulted anticline formed in the early Miocene age shortly after deposition of the sandstone formation. The trapping mechanism is both structure and stratigraphy with hydrocarbon deposits found in six immature fluvial or distributary channel sandstone formations from 3200' to 3700' subsea depth1. Most Widuri wells are gravel packed initially in an individual sand formation and produced using electrical submersible pumps. The subject of this paper, WIA-8 well, is gravel packed in the 35-1 formation which is unconsolidated sand with a log porosity of 29% and a test permeability of 5 Darcies.
After completion, some Widuri wells had experienced a productivity impairment. In August 1990, laboratory analysis was commenced to investigate the cause of the impairment and to determine an appropriate treatment. The results lead to performing subsequent matrix treatments on the WIA-8 well (Figure 2). In February 1992, a hot solvent treatment pumped into the well resulted in an additional productivity impairment. In April 1992, a retarded mud acid treatment performed in the well caused a severe productivity impairment. In November 1992, a revised retarded mud acid treatment with an improved clay stabilizer pumped into the well did not improve the productivity impairment.
The Drilled Well Scorecard: A Step to Building a Learning Organization
Authors: Brooker M. W. , Walker M. J. , Brett J. F. 
Published: December 2007

ABSTRACT
Performance measurement is useless if it does not lead to process improvement. Evaluation of individual functional areas alone will not necessarily lead to a better overall process. The effectiveness of process inputs, outputs, and actions must be measured against the organization's underlying goals. UPRC is not in business just to drill holes in the ground; UPRC is in business to make money. Ideally, all actions in the process should reflect this goal.
To describe this whole system phenomena, we have developed a relational control model of the drilling process. Together, UPRC and OGCI designed a performance measurement system, the Drilled Well Scorecard, to reflect the relationships in this model and to make performance evaluations that will lead to real, continuous improvement. The scorecard was designed to facilitate communication across teams, to document project goals and assumptions, to measure the effectiveness of drilling plans in meeting these goals, and to reconcile the differences between intended and actual results.
If these scorecards are used for post-analysis and then to help plan future projects, they can facilitate organizational learning. A learning organization must: • define specific goals linked with its financial performance • ensure that actions are directed at meeting these goals • "remember" how decisions were made • build an accessible reservoir of experience, of the right expertise and technology • accurately monitor performance »use this experience to adapt its practices to "do it better next time.
When the organization uses the scorecards as system feedback, it will be able to capture the benefits of it's experience. The company is planning to use the experience stored on the "Drilled Well Scorecard" as part of an effort to improve both it's planning process and it's project execution, as a step to building a learning organization. Again, this should be the ultimate goal of any performance measurement program.
Safety Performance Monitoring for Drilling: A More Comprehensive System
Authors: Lievre Thierry 
Published: December 2007

Abstract
The Frequency Rates generally used in safety statistics for Lost Time Injuries and Minor Injuries provide measurement only on consequences and not on causes. As such they cannot help much in improving the safety performance of one particular operation or contract, especially for short term contracts. This paper describes a system which enables an early detection of failures of the safety management systems, before such failures lead to injuries. This system improved the safety performances of drilling rigs around the world, which resulted in a company Lost Time Accident Frequency rates divided by two.
Cuttings Re-injection on Mature Platforms: a Case History
Authors: van Gils J. M. I. , Thornton T. J. O. , Kece M. , Bennett W. , Yule G. K. 
Published: December 2007

ABSTRACT
The paper summarises the experiences gained to date during the successful installation and six months' operation of cuttings reinjection (CRI) equipment on a major Operator's mature northern North Sea platforms.
Consideration is given to the constraints that mature platforms impose on the design in terms of power availablility, weight and space limitations, and personnel-on-board, as well as problems overcome in locating the CRI processing equipment away from the solids control package.
Other issues addressed in the paper include the rationale for the selection of injection candidates from existing wells; well integrity and wellhead erosion, including the results of erosion tests performed onshore; and operational experience.
The paper concludes that CRI is a practical solution to the tightening governmental legislation on discharges to the sea, allowing the unrestricted use of mineral oil based drilling muds for the extended reach and horizontal wells critical to the future of the Operator's field development.
Drilling Fluid Disposal System
Authors: Haymes R. D. , Daily S. C. , McGowin J. L. 
Published: December 2007

Abstract
A superior method of downhole annular disposal of drilling mud waste has been developed utilizing external casing packers and a modified port collar to isolate a predetermined disposal zone. The benefits of this system are that it reduces the risk of contamination of fresh (potable) water sources and greatly reduces the risk of jeopardizing the mechanical integrity of the well.
The conventional method of disposing of water-based drilling mud by evaporation/dewatering and backfilling of the reserve pit in many cases is no longer allowed, due to the protection of aquifers, hydrologically sensitive areas (HSA), and wellhead protection areas (WPA) in the State of Oklahoma. The use of geomembrane or soil liners is required in these areas.
The common methods of water-based drilling mud disposal in these areas are the following: Chemical solidification of pit contentsDisposal in a permitted commercial injection wellDownhole annular injection.
Low Cost Slim Hole Drilling System
Authors: Beswick A. J. , Hills D. L. 
Published: December 2007

ABSTRACT
Interest in reducing the cost of exploration in frontier areas and in areas of special environmental concern has given rise to a variety of initiatives to develop ‘slim hole’ drilling systems and down hole tools. The market over capacity of conventional rigs offered at unrealistic commercial rates masks the real cost of operating heavy drilling equipment. This acts as a disincentive to the development of smaller innovative drilling rigs and associated equipment and the development of a smaller scale drilling system that has wide acceptance in the industry. Furthermore, funding for development of such systems has been sadly lacking.
In response to a contractual commitment, an opportunity arose to design and construct a small, low cost drilling system suitable for a range of slim hole and downsized drilling scenarios. In this particular case, the equipment was required to drill both vertical and slant boreholes with slant angles up to 45°. The drilling unit and associated equipment combine a blend of oilfield and mining ideas with the objective of demonstrating that a low cost unit could satisfy the requirements of the industry for frontier drilling.
The drilling unit is capable of both conventional destructive drilling up to 17-1/2 in diameter and continuous coring using heavy duty systems up to 6-1/4 in hole size. The singles rig is 100 ton capacity with a rotary capability from the top drive system of up to 400 rpm which gives a slim hole capability of over 3500 m.
The mechanised pipe handling system includes a hydraulic clamping device within the top drive head and an elevating and extending catwalk with hydraulic power breaker capable of breaking 8 in drill collars. The handling System will accommodate 13-3/8 in Range 3 casing. Triplex mud pumps, power pack and generators are housed in acoustic containers. The rig and associated equipment is designed to oilfield standards and all pressure lines are rated to 5000 lb/in2. A BOP handling system is included especially to cater for slant drilling and a hydraulic crane mounted at drill floor level together with a tugger winch provides general handling facilities around the rig. All main rig units are configured to 6 m ISO container standards for ease of shipping and port handling including mud tanks.
The rig includes a comprehensive computerised rig instrumentation system with a local computer network for the site and a sensitive automatic drilling facility operating through the hydraulic drawworks winch control system.
The paper describes the background philosophy, the equipment and the initial operations since commissioning the equipment in June 1994.
New Bi-Center Technology Proves Effective in Slim Hole Horizontal Well
Authors: Sketchler B. C. , Fielder C. M. , Lee B. E. 
Published: December 2007

ABSTRACT
This paper describes the design and application of new bi-center bit technology in the Bay Marchand Field (offshore Louisiana). A bi-center bit and tandem motor assembly were used to simultaneously drill, underream, and directionally control a slim hole horizontal re-entry well using conventional directional techniques. This new bi-center technology significantly reduced cost for underreaming and eliminated the risk associated with the use of underreamers in a slim hole, high angle environment.
A New Development Towards Improved Synthetic Based Mud Performance
Authors: McKee J. D. A. , Dowrick Kevin , Astleford S. J. 
Published: December 2007

ABSTRACT
This paper describes a new synthetic based drilling fluid (SBM) which is able to emulate oil based mud performance whilst complying with environmental legislation. Comparisons with oil based mud in the laboratory show that the system can provide similar performance at low synthetic:water ratio, high mud weight, high temperature and in the presence of contaminants. The laboratory results are supported by field data which demonstrate that the system can be managed like mineral oil based mud, giving good rates of penetration with minimum mud maintenance and low retentioh of the synthetic base fluid on cuttings discharged to the sea.
Marine toxicity, bioaccumulation and biodegradation data has been compiled for the SBM and the synthetic base fluid. Based on these results, the system has been accepted for use in UK and Norwegian waters, subject to Sea bed surveys following its use in trial wells. In the UK, the system has been placed in provisional Group E of the revised Offshore Chemical Notification Scheme (OCNS)1 product categorisation. For operations in the United States, the mysid shrimp 96 hour LC50 toxicity test result significantly exceeds the limit required for use in the Western Gulf of Mexico outer continental shelf.
Drilling Onshore People's Republic of China Utilizing a Chinese Contractor
Authors: Switzer S. S. , Frisbie J. W. , Malpas Peter 
Published: December 2007

Abstract
This paper reviews Fletcher Challenge Petroleum's experience in drilling a well onshore China utilising a Chinese drilling contractor. It details our approach to the project, the results achieved, and covers the full operations cycle from initial evaluation of the Chinese contractor's capabilities through their performance on the well drilled. This information provides insight and knowledge to Western operators who may work onshore China in the future.
Main Contractor's View Point of the Lekhwair Turnkey Project: Case History
Authors: Dudouet Michel , DeGuillaume Jacques 
Published: December 2007

Abstract
As part of the field development plan for the LEKHWAIR A-North oil field in the northern desert of OMAN, Petroleum Development of Oman (P.D.O.) has initiated middle of 1990 a Turnkey Drilling Project.
Galfar Engineering & Contracting of Oman and Forasol of France, by their joint-venture company (resp. 70/30 interests) National Drilling & Services Company LLC (N.D.S.C.) have been awarded the contract in november 1990 and have then initiated the challenging project. It started by the new construction of two purpose-built highly movable desert rigs and led to the spud of the 1st well, September 18th 1991 in the way to meet demanding targets (as to complete the first 25 wells by February 1st 1992). Simultaneously a turnkey drilling organization was installed locally in conjunction with well service companies and logistical/civil works forces to assume and supervise petroleum engineering functions and supplementary responsabilities, which were integrated in the Lekhwair Turnkey Drilling Contract. A total of 115 medium depth wells (94vertical at 1320/1330 m or deviated, plus 21 horizontal wells) were drilled on such a turnkey basis up to august 1993. Thus allowed the main contractor to handle new specialities like well completion services or managing of horizontal drilling directional package, simultaneously to the task of running operations in the hostile Omani desert; it appeared that the mode of new or improved drilling technology helped strongly to resolve this challenging context.
The paper will firstly give the various stages of the project, detailing scope of work, integration of drilling and completion services, QA/QC-safety management system, and rig design.
Secondly, we will analyze the general performances, highlighting the areas of particular importance (learning curve evolution, well acceptance relationship).
In the third instance main learning points are set up.
To conclude, we will give our opinion on how similar type of project should be approached in future.
A Case History of Completing and Fracture Stimulating a Horizontal Well
Authors: Abass Hazim H. , Hagist Peter , Harry James , Hunt James L. , Shumway Mark , Gazi Naz 
Published: December 2007

Abstract
This paper presents a detailed description of the completion and fracture stimulation of a high-angle well in the Madison formation of the Williston Basin in North Dakota. The case history of the Candee 26-13 HA well is used. The completion and fracture stimulation techniques used on this well resulted in a three and a half-fold increase in the ultimate recovery of the well, in comparison to a vertical well in the same field.
The well was directionally drilled to intersect natural fractures and provide optimal conditions for hydraulic fracture stimulation. To ensure zone selectivity and isolation, the well was cased and cemented. Notching techniques were used to allow hydraulic fracture treatments to be selectively initiated along the wellbore. Matrix acidizing was an essential phase to achieve this goal.
This paper also presents a discussion of how reservoir simulators can be used to optimize the number of fractures needed to cover a given drainage area. In addition, prefracture and postfracture evaluations are discussed.
Investigation of Intermittent Gas Lift by Using Mechanistic Modeling
Authors: Liao Tianlu , Schmidt Zelimir , Doty D. R. 
Published: December 2007

ABSTRACT
Intermittent gas lift is a cyclic process which can be divided into four stages. This paper describes a mechanistic model for the intermittent gas lift system based on fundamental physical principles. The model accounts for reservoir inflow performance, fluid properties, two-phase flow in the tubing, gas flow in the tubing-casing annulus, the performance of a gas-lift valve and a surface gas injection choke, and various intermittent gas-lift control mechanisms. The mathematical model consists of a system of ordinary and partial differential equations for each of the four stages. The resulting system of equations is numerically solved. The model is capable of generating the detailed cyclic characteristics and the overall performance of an intermittent gas-lift system. The model is validated using experimental data collected by a number of previous investigators. These data cover a wide range of operating conditions for intermittent gas lift The model's predictions compare well with the experimental measurements. The effects of various system parameters on the performance of the intermittent gas-lift system are studied using the model, and the most important controlling parameters are identified. The ability to identify these controlling parameters and their optimum values for a given system allows one to operate an intermittent gas-lift system more efficiently. Finally, the performance of intermittent and continuous gas lift are compared, and qualitative guidelines are outlined for selecting between intermittent and continuous gas-lift methods.
Coiled Tubing Working Life Prediction
Authors: Wu Jiang 
Published: December 2007

ABSTRACT
Failure of coiled tubing, due to the repeated bending and plastic deformation of coiled tubing on and off the reel and gooseneck, is of great concern in coiled tubing operations. This paper discusses the coiled tubing working life based on one of the coiled tubing life models published in the literature, and compares the results with other models. Certain agreements are found among these models.
A group of curves is presented to illustrate the coiled tubing working life affected by coiled tubing size and wall thickness, internal pressure, yield strength, reel diameter, gooseneck radius, operation condition (corrosion) and butt- welded connection (stress concentration). The results show that coiled tubing life can be greatly increased by increasing CT wall thickness and CT strength, while the coiled tubing working life decreases under high internal pressure, corrosion, and butt-weld conditions. These curves can be easily used in estimating coiled tubing life for the field use.
Thickness Optimization of Drilling Fluid Filter Cakes for Cement Slurry Filtrate Control and Long-Term Zonal Isolation
Authors: Griffith James E. , Osisanya Samuel 
Published: December 2007

Abstract
In this paper, the long-term isolation characteristics of two typical filter-cake systems in a gas or water environment are investigated. The test models were designed to measure the sealing capability of a premium cement and filter-cake system used to prevent hydraulic communication at a permeable-nonpermeable boundary. The test models represented the area of a sand-stone/shale layer in an actual well. In a real well, sandstone is a water- or gas-bearing formation, and sealing the annulus at the shale formation would prevent hydraulic communication to an upper productive zone. To simulate these conditions, the test models remained in a gas or water environment at either 80° or 150°F for periods of 3, 4, 30, and 90 days before the hydraulic isolation measurements were conducted. Models without filter cake, consisting of 100% cement, were tested for zonal isolation with the filter-cake models to provide reference points.
Results show that at 80°F, all filter cakes tested provided adequate zonal isolation up to 90 days. However, at 150°F, the reduction in filter-cake thickness prevented communication at higher pressures, The two highest pressures recorded occurred when no filter cake was on a water-saturated core. The next three highest pressures were measured with no filter cake on a gas-saturated core.
These results show how critical filter-cake removal is to the long-term sealing of the cemented annulus. Results indicate that complete removal of the filter cake provides the greatest resistance to fluid communication in most of the cases studied.
Shut-Off of a Geopressured Water Channel Behind Casing via Coiled Tubing Utilizing a Dual Slurry Cement System: A Case History
Authors: Nowak T. W. , Lange K. J. , Grant W. H. , Patout T. S. 
Published: December 2007

Abstract
This paper presents a case history involving a unique dual cement system to shut off a geopressured water channel behind casing utilizing coiled tubing. The channeling problem was identified and documented using water flow logging techniques. Logging indicated the lower gravel packed selective could produce salt water if perforated without eliminating the suspected water channel. Reserves did not warrant a major rig workover, making a non-rig workover via coiled tubing the only viable option to repair the well. A unique dual cement system tested on a hesitation squeeze schedule pumped through coiled tubing with extremely limited thickening time was necessary to repair the primary cement job.
Investigation of Procedures and Economics of Spill Site Remediation in Southeast New Mexico
Authors: Abbott Dave , Hillard Jerry D. 
Published: December 2007

Abstract
A pilot field study was initiated to evaluate the feasibility of remediating produced water and hydro-carbon contaminated soils along produced water gathering lines and disposal facilities in Southeast New Mexico. The soils were contaminated by leaks occurring adjacent to gathering lines and along Right-of-Ways over a 30 year time frame.