bluuebunny/crossref_metadata_2025_split huggingface dataset:
Managing Risks and Uncertainties in Drill Cuttings Re-Injection in Challenging Environments – Field Experience from Sakhalin Island
Authors: Guo Q. , Geehan T. , Pincock M. 
Published: December 2007

Abstract
Drilling waste disposal using hydraulic fracturing is often the preferred waste management option because it can achieve true zero discharge without being limited by the drilling location. This is particularly true for drilling operations in remote and challenging areas such as offshore Sakhalin Island as there is no established infrastructure for drilling waste management.
This paper presents a case history of managing uncertainties and risks related to a drill cuttings re-injection (CRI) project offshore Sakhalin Island. Although there are uncertainties and risks with the CRI project in this case, regulatory requirements and the operator’s commitment to zero discharge made it the preferred option for drilling waste management. Complicating the decision was a previous injection well where cuttings settling made it inoperative. Thus, the only option was to inject the oily cuttings into a deviated well intended for future use as a development well, which posed a number of risks related to the proposed CRI operation.
Since this is the only option for drilling waste management and loss of this well would have delayed the drilling program and field development for at least a year, managing the risks and uncertainties related to this CRI project and assurance of a trouble-free CRI operation were critical.
This paper presents monitoring and diagnostic analyses that were used for slurry design and optimization, pumping procedure design and optimization considerations, as well as solids transport modeling and planning length of shut-in intervals between batches. These quality assurance and optimization measures were proven to be effective in managing the risks and uncertainties associated with this critical cuttings injection well off Sakhalin Island. At the time of this writing, more than 100,000 bbl of slurry and fluid had been injected into this well without incident.
SSC Resistance of QT-900 Coiled Tubing
Authors: McCoy T. 
Published: December 2007

Abstract
Laboratory sulfide stress cracking (SSC) tests were performed on specimens taken from a QT-900 coiled-tubing test string in an attempt to define zones of acceptable sour service. SSC tests were performed at room temperature in brine fluid environments with H2S partial pressures (PH2S) ranging from 0.01 to 10 bars and pH levels from 2.8 to 4.5. In addition, the effectiveness of a new inhibitor for crack prevention was tested. SSC testing, which included NACE Method A tensile, four-point bent beam and slow strain rate test specimens, were performed on as-milled as well as fatigue-cycled tubing. Fatigue cycling of the QT-900 test string was performed on a pressure bending fatigue machine with tubing samples cycled from 33% to 75% of average tested fatigue life. Test specimens were taken from parent metal, bias weld, seam weld (ERW), and butt weld locations. As a result of this test program, acceptable zones of service in sour environments have been proposed although further testing may alter boundary locations.
The Malaan Area of Northern Oman: PDO Opens up an Unconventional Play
Authors: Hiebert S. , Mazrui M. , Al-Harthy M. , Harris K. , Shuster M. , Hadhrami M. A. , Blonk B. 
Published: December 2007

Summary
In the northwest area of Petroleum Development Oman's (referred to later in this paper as ‘PDO’) concession, substantial oil volumes have been discovered in conventional structures trapping low permeability carbonates of both the Upper and Lower units of the Cretaceous Shuaiba Formation. However, since full-scale development of the area began, only a fraction of production has come from the Upper Shuaiba. Previous drilling campaigns targeting Upper Shuaiba have met with limited commercial success, because oil-charged reservoir occurs in thin pay (1-5m), and production test rates from the mostly vertical wells are generally less than 100 bbl/d. In late 2000, an exploration well was drilled on the crest of the Malaan structure, and similar to many previous tests in the area, encountered oil in several thin units of very low permeability (2-10 mD), but failed to flow at a sustainable rate. Subsequent reprocessing and inversion of the seismic, combined with a revised geological model which was partly based on experience of neighbouring operators, indicated the possibility of a higher porosity and permeability trend considerably down the flank of the Malaan structure. The trend is coincident with a top-lap truncation imaged on seismic, forming elements of a stratigraphic trap with the overlying Nahr Umr Shale.
In July 2003, the Malaan-2 well was spudded approximately 3 km northwest and 29m down flank of Malaan-1, and found significantly better reservoir quality. New logging while drilling technology (LWD) from Schlumberger, used for the first time in the world in an exploration well, was critical to maintain the horizontal well path in the best quality reservoir rock. The well has been tested and hooked up, and appears to have a stable production rate of over 1400 bbl/d net oil.
Seismic imaging shows that the best reservoir is coincident with an amplitude anomaly which extends more than 20km in a south-westerly arc, and which is independent of current structure. Forward modeling, incorporating all well data, has now allowed a match between synthetic and real seismic, and giving more confidence in the geologic model.
The trapping mechanism, and the factors controlling oil saturation, are not fully understood; the area has recently undergone regional structural tilting, and it is possible that the hydrocarbons are not yet in equilibrium. Several appraisal wells planned for 2004 will further delineate the extent of the accumulation and provide a better understanding of the trap. In a success case, the elements of this exploration play will be applied to other similar seismic trends already identified across northwest Oman.
Global Environmental Perfomance Indicators in an E&P Service Company
Authors: Sealy I. 
Published: December 2007

Proposal
The paper describes the development, implementation and application of a program of environmental performance measurement in a global service company working the in exploration & production industry.
A set of environmental performance indicators has been defined in order to provide data on internal compliance, environmental incidents, resource consumption, and waste generation (and management). Information is captured in an on-line database from over 500 sites in approximately 100 countries, on a monthly basis, and is immediately available for analysis and management review. The paper discusses the selection of the indicators that are used, and the intended value of each indicator, or group of indicators.
Having described the basis for the EPI program, examples from the data capture and management review process are presented. These examples are used to illustrate the evolution of the EPI process over the past three years. There is particular emphasis on discussion of the challenges that are presented by a highly devolved and decentralized data capture process.
The third section of the paper concerns the trends and themes that are evident from the database, and their application and value to the management process. There is a discussion of indicators that have been removed from, or added to the program and the reasons for those changes.
The paper concludes with a discussion of the possible areas for future development of the program.
Restoring Integrity to Aged Petroleum-Production Facilities
Authors: Ciaraldi S. W. , Hedges B. 
Published: December 2007

Abstract
BP and its local predecessor Amoco have produced oil and gas off the east coast of Trinidad for over 30 years. This production originates from eight offshore fields and is transported to onshore terminals through an extensive pipeline network. Gas is further shipped for domestic use or LNG production. Oil is temporarily stored onshore and then tanker loaded for export. Despite excellent business success for the operator and nation, maturing production, long service time and constrained resources have taken a toll on the technical integrity of facilities.
In late 2000, a major program to restore integrity was developed, resourced and implementation begun. The restoration strategy was based on a four-step process involving assess, restore, upgrade and sustain. The program addresses the technical integrity of all assets including offshore topsides, subsea structures/pipelines, onshore terminals, tankage and oil/gas exports systems. It also includes enhancements to process safety protective systems and development of a comprehensive major accident hazards management system.
This paper outlines the many problems, solutions, challenges and successes of the integrity restoration program. It describes the required organizational commitment to a multi-year improvement campaign and a shared vision of sustained, world-class integrity management. Lessons learned from the program are now being applied to BP Indonesia operations offshore Java and elsewhere; specific areas of corporate sharing are described.
Sand Production Prediction and the Selection of Completion Methods for Horizontal Wells in Intercampo Oil Field, Venezuela
Authors: Hong'en D. , Dandan H. , Wenxin C. 
Published: December 2007

Abstract
Intercampo oilfield is unconsolidated sand reservoirs that are characterized by heavy crude oil and mid-high permeability and high saturation. This paper analyses sand production mechanism and applies five prediction models to predict sand production. Sand production condition of wells in Intercampo oilfield indicates that prediction results are to meet with oilfield actual status that sand production to occur seriously and the method of the combination modulus is more accurate than other models according to wells of acoustic logging data.
This paper considers the effect of formation damage and well completion parameters of different well completion methods on productivity forecast of horizontal wells with four series of well completion, including open hole, slotted liner with openhole, open hole gravel packing with wire wrapped/pre-packed screen and cased perforated completion. And, the productivity forecast equations were corrected by authors, the corrected equation is accuracy compared with the former equations by calculation, and one well completion method that open hole with gravel packing and pre-packed screen was selected. Sine 1999, the selected well completion method have been applied in Intercampo oilfield of CNPC in Lake of Maracaibo and obtained higher productivity than other completion methods of other companies. The sand production was effectively controlled and the oilfield was continuously kept sand free for 5 years in the area. Finally, a good economic benefit was gained because the workover and well re-completion in the oilfield for sand control was down.
Thermochemical Solution for Removal of Organic Solids Deposit in and Around Wellbore and Production Tubing
Authors: Ibrahim J. M. , Ali K. 
Published: December 2007

Abstract
During production of crude oil, temperature and pressure of the produced fluid decreases along its production pathway. The reduction in pressure and temperature disturbs the equilibrium of the composition of the oil particularly the heavier components leading to their separation, precipitation and deposition at in-and-around well bore (skin effect) and production tubing. Such a deposition can choke the flow passage from reservoir to well bore and reduce the production of oil appreciably (Diagram 1).
A unique two pack chemical system had been developed as an effective tool for:
Removal of organic deposits, such as in-and around well bore (skin) and production tubing Enhancement of production rate
The two pack chemical system when injected into the well bore through production tubing, reacts to produce in-situ heat with a reaction product. The heat generated in the system can dislodge and melt the deposits and the reaction product formed acts as dispersant and an effective surfactant.
The paper presents the results on two wells which were pilot implemented in Malaysian Offshore field, Temana (TE). Among the two treated wells, one well was a closed-in well while the other was gas lift producing well. Both wells had shown appreciable decrease in skin factor, reduction in water production and sustained an additional average incremental production of 190 to 320 bpd for the past one year. Pay back period of the treatment cost was between 11 to 19 days. The wells are still producing after one year of treatment.
The two pack chemicals system and related chemicals, and their reaction product are compatible with crude oil, rock formation, tubular steels and oil field rubber parts.
Foam Characterization Using Image Processing Techniques
Authors: Ozbayoglu E. M. , Akin S. , Eren T. 
Published: December 2007

Abstract
Foam has been used in petroleum industry as a fracturing fluid and a drilling circulation fluid for many years. Proper determination of volumetric requirements for gas and liquid phase of foam during drilling and fracturing applications is directly related with an accurate foam characterization. It has been observed that, bubble size and texture of foam has an influence on foam rheology, however, no mathematical description has been introduced for their effect. The idea behind conducting this study is to get a more comprehensive method of foam rheology definition in which the bubble size and texture effects of the foam are considered. Three different analysis methodologies are introduced; i) Generalized Volume Equalized approach, ii) Generalized Volume Equalized Approach + Image Processing data, and iii) Image Processing data only. The necessary information including the rheological information and image data is acquired from the developed set-up for this study. It has been observed that, the pressure losses could be predicted as a function of bubble size, circularity, and general rheological parameters, in ±20% certainty limit. It is also observed that using only the image information could also be used for characterizing the foam in an accurate and fast manner.
Cyclic Steam Well Design—A New Approach to Solve an Old Problem of Cement Sheath Failure in Cyclic Steam Wells
Authors: Bour D. 
Published: December 2007

ProposalSteam injection is often used to increase oil production in heavy-oil fields. While the concept of thinning heavy oil by raising the temperature though steam injection is a fairly simple one, the associated challenges of designing and constructing a well for this environment can be complicated. One specific challenge is to construct a well where the cement sheath(s) will not fail and allow interzonal communication. The temperature fluctuations and the associated mechanical stresses transmitted to the cement sheath can cause the cement to crack. This cement failure can lead to steam injection migrating to zones other than the injection target zone, loss of production, communication of corrosive fluids in the annulus, casing movement, and other associated problems.Another factor that can affect the durability of the cement is the mechanical properties of the formations in which these wells are drilled. Excessively soft or low Young's Modulus formations exacerbate the problem by providing minimal confining stress on the cement sheath. In addition, wells drilled in a steam-flood field can often be plagued by lost-circulation problems, requiring use of low-density cements to address problems in cement placement.This paper provides details on how to help construct a well under these difficult conditions with minimal or no cement-sheath failure in critical production zones. Finite elemental analysis (FEA) shows that conventional and even specialized cement blends alone may not stand up to stresses encountered under these conditions. A unique technique is provided and verified with FEA to show how a well might be constructed without cement-sheath failure or at least minimal failure in critical zones. In addition, FEA analysis is provided to show how to help (1) optimize casing sizes and weights and (2) minimize costs of construction.
Problem of Monitoring of Arbitrary Oriented Trajectories of Boreholes with Small Diameters by Means of Strapdown Gyroscopic Inclinometers and its Solution Methods
Authors: Binder Y. I. , Okon I. M. , Paderina T. V. , Rozentsvein V. G. 
Published: December 2007

Abstract
The possibility to use two-axis gyro rate sensor (GRS) in principle for measurement of trajectory parameters is shown., in the present report. The angular momentum vector of this sensor is oriented along the longitudinal axis of the borehole device. The errors and limits of this scheme utilization are defined, when operating in gyrocompassing mode. A method of utilization of the scheme with a longitudial gyro is original for two operation modes (gyrocompassing and analytical directional gyro) near the line West-East. The errors intrinsic to such a combined operation mode are analyzed.
In order to eliminate the restrictions typical for inclinometer with a longitudinal gyro, it was proposed to arrange GRS with angular momentum in the cross-section plane of the borehole. And with this, a method of inclinometer utilization was develop, which permits not only to solve the "accuracy loss zone" problem but also to eliminate effect of the gyro drift changeability caused both by its utilization period and the gyro start-up errors.
For the first time calibration of the gyro during operation is proposed by slewing the gyro housing about two multually perpendicular axes: the main sensor axis and the boring column axis. Algorithms on multiposition gyrocompassing of such a single-gyro system are proposed and analyzed.
Experimental results confirming the main conclusions of the teoretical investigations are presented.
Verification of Decline Curve Analysis Models for Production Prediction
Authors: Li K. , Horne R. N. 
Published: December 2007

Abstract
Reserves and production in petroleum reservoirs can be estimated using empirical and analytical decline curve analysis models. There have been many such models. In this study, three representative models (exponential, harmonic, and the mechanistic Li-Horne models) were chosen to predict and match oil and gas production from both core samples and reservoirs with different permeability. The recovery and reserves were estimated using the three models and the results were compared. The comparison demonstrated that the recovery at an assumed economic limit predicted using the Li-Horne model was greater than the exponential model but was less than the harmonic model. Note that the exponential model tends to underestimate reserves and production rates while the harmonic model has a tendency to overpredict the reservoir performance. It was also found that the reserves predicted using the harmonic model were greater than one pore volume in some cases, which is physically impossible. The model predictions using the experimental data of recovery in the core samples were also compared to the true values. The results demonstrated that the Li-Horne model had the best estimation of the recoverable recovery compared to the exponential and the harmonic models in the cases studied.
Monitoring Waterflood Operations: Hall's Method Revisited
Authors: Silin D. B. , Holtzman R. , Patzek T. W. , Brink J. L. 
Published: December 2007

Abstract
Hall's method is a tool for evaluation of an injecting well performance. It is based on the assumption of radial steady-state flow. Besides time series of historical injection pressures and rates, rigorous implementation of Hall's method requires information about the ambient reservoir pressure. In addition, it is assumed that the influence domain radius is constant during the observation period. Neither of these parameters can be measured directly.
This paper discusses a new method called slope analysis. It is based on analysis of the variations of the slope of the plot of the time integral of pressures versus cumulative injection volume. In particular, it produces an estimate of an apparent average reservoir pressure. This method requires only injection pressures and rates data, which are routinely collected in the course of a waterflood. Thus, slope analysis requires no interruption of regular field operations.
The method has been verified with numerically generated pressure and rate data, and tested with field data. In both cases it proved to be accurate, efficient, and simple. The estimated ambient reservoir pressure can be used to correct the Hall plot analysis or to map the average reservoir pressure over several patterns or an entire waterflood project. Such maps can then be used to develop an efficient waterflood policy, which will help to arrest subsidence and improve oil recovery.
Towards An Adaptive, High-Resolution Simulator for Steam Injection Processes
Authors: Nilsson J. , Gerritsen M. , Younis R. 
Published: December 2007

Abstract
We develop a computationally efficient and accurate adaptive simulation model that is specifically designed for non-isothermal and compositional recovery methods, including steam injection, in-situ combustion and miscible gas injection. The adaptivity is designed to accurately resolve fronts that typically form in the reservoir during such processes. Owing to steep gradients in the solution as well as the strong nonlinearities due to thermal and compositional effects, accurate adaptive modeling is challenging. It is difficult to achieve without appropriate high-order discretization and strong grid refinement. Our framework is based on a Cartesian Cell-based Anisotropic Refinement (CCAR) strategy. CCAR offers aggressive grid adaptation, which allows quick transition to the very fine local grids necessary to resolve solution fronts and the fine local grids desirable to resolve reservoir heterogeneity. We have formulated a higher order pressure solver on the CCAR grids. The discretization uses a compact stencil, which together with an effective storage scheme leads to computational efficiency.
We apply the framework in this paper to a black-oil steam formulation. Although simplified, the simulation demonstrates the main features of our adaptive strategy.