bluuebunny/crossref_metadata_2025_split huggingface dataset:
Conversion of Mature Steamfloods to Low-Quality Steam and/or Hot-Water Injection Projects
Authors: Ault J. W. , Johnson W. M. , Kamilos G. N. 
Published: December 2007

ABSTRACT
Three of Chevron's successful Kern River Field Steam Drive Projects (Section 3, Monte Cristo II, and American Naphtha) have been converted to either hot waterfloods or low quality (10%) steam injection projects. The projects' net oil production has increased significantly because of the reduced oil consumption at the steam generators. In general, the conversion to low quality steam or hot water injection has improved the oil production response of each project.
Production and reservoir data suggest that improved sweep efficiency in the lower part of the steam driven sands occurred as a result of the switch from high steam quality injection to reduced steam quality. This paper discusses the performance of these three projects. Production and reservoir parameters are identified which can be used to determine the timing for conversion of a mature steamflood to a lower quality steam injection project.
Using Numerical Simulation To Determine the Optimum Completion Interval for Steam Stimulation Wells, Section 34, North Midway Field, Kern County, CA
Authors: Brinker S. D. 
Published: December 2007

ABSTRACT
The production of fluids from a heavy oil reservoir results in a "desaturated" zone of compressible gasses at the top of the formation. This zone can act as a steam thief zone during steam stimulation. A computer simulation study was made to determine if having a smaller interval open in a well could prevent the loss of steam to the desaturated zone and increase production. The study showed that with very thick formations (&gt;250 feet), the optimum production was obtained with 74-55 percent of the net interval completed. For thinner sands (&lt;250 feet), optimum production was obtained by completing as much of the net zone as possible.
Two Successful Steam/Foam Field Tests, Sections 15A and 26C, Midway-Sunset Field
Authors: Ploeg J. F. , Duerksen J. H. 
Published: December 2007

Abstract
Two successful steam-diverting field tests were conducted at the Midway-Sunset Field in the San Joaquin Valley, California. A Chevron proprietary sulfonate was used as a steam-diverting agent to improve oil recovery. The results showed that, for the conditions of the field experiment, the sulfonate used is very economic, significantly increasing oil recovery. Also, there were no associated sulfonate-handling and produced oil-treating problems.
Downward Two-Phase Flow Effects in Heat-Loss and Pressure-Drop Modeling of Steam Injection Wells
Authors: Galate J. W. , Mitchell R. F. 
Published: December 2007

Abstract
Modelling of the pressure drop and heat loss in steam injection wells has undergone a gradual evolution since the heavy interest in enhanced oil recovery by steam injection in the mid-60's. After briefly reviewing the evolution of steam models this paper presents a model which advances the state-of-the-art of steam modelling.
The main advance presented in this paper is modelling the effects of the various flow regimes that occur during steam injection. The paper describes the formulation of a two-phase downward vertical flow pressure drop model which is not limited by the "no-slip" homogeneous flow assumptions in most previously published models. By using different correlations for mist, bubble, and slug flow, improved pressure drop calculations result, which in turn improve temperature predictions. The paper describes how the model handles temperature predictions differently in the single and two-phase steam flow situations.
The paper also describes special features in the model to account for layered soil properties, soil dry out, cyclic injection, coupling heat losses, and reflux boiling in wet annuli. Two examples problems are presented which illustrate some of these features.
Pilot Gas-Lift System at Prudhoe Bay
Authors: Hanson E. S. 
Published: December 2007

ABSTRACT
This paper discusses the design concepts and operating experiences of a small, twelve-well gas lift system in a unique arctic environment. The project was undertaken by Sohio Alaska Petroleum Company as operator for the Western Operating Area of the Prudhoe Bay Unit. This pilot system provided valuable operating data prior to the startup of the full field gas lift system which, in its final configuration, will be the largest gas lift facility in the United States.
This paper illustrates the intimate interaction of all of the variables that can affect gas lift such as supply pressure, separator pressure, tubing hydraulics, flowline hydraulics, geothermal temperature gradient, and gas lift valve characteristics. It also addresses some of the concerns that are unique to the operation of gas lift systems in an arctic environment.
One-Trip Perforate and Gravel Pack System
Authors: Hailey T. T. , Donovan J. F. , Van Sickle E. W. 
Published: December 2007

Abstract
A downhole tool system has been developed that makes it possible to perforate well casing with all the advantages of a TCP (Tubing Conveyed Perforating) gun and to gravel pack that well using proven techniques, all on the same trip in the hole. The system has been operated successfully in 7-5/8″, 7″ and 5″ casing, and is also available for 5-1/2″ and 9-5/8″ casing. The system has been in development for about 2 years in the Texas and Louisiana Gulf Coast area, in cooperation with several different operators and under varying well conditions.
The main components of the system are a casing sized TCP gun, a hookwall packer which is multiple acting and operated by reciprocation of the workstring only, screen and blank pipe common to gravel packed completions, and a hydraulically set seal bore packer.
The operation of the system is as follows:
–– As the system is run in the hole, a radioactive tag is installed in the workstring at a known distance from the TCP gun. With the gun at approximate perforating depth based on pipe measurements, a gamma ray logging tool is used to locate the tag and correlate its position back to previous logs. Knowing the exact location of the tag, the gun is re-positioned precisely for perforating. –– The hookwall packer, just above the gun in the assembly, is set and tested, then a bypass is opened allowing circulation through the packer. Lightweight fluid is then circulated down the workstring and the packer bypass is closed, creating an underbalanced pressure in the wellbore compared to reservoir pressure. –– The gun is then detonated by dropping a detonating bar or pressuring the workstring-casing annulus, depending on whether a mechanical or hydraulic firing head is used. The well can be flowed as necessary for clean up and testing. –– The well is killed by unsetting the hookwall packer and reverse circulating kill weight fluid into the workstring. –– The entire assembly is moved downhole and the hookwall packer is reset below the just-perforated interval. The seal bore packer is then hydraulically set by dropping a ball into the workstring and pressuring against the ball. This setting operation also converts a tool inside the packer to a dual flow path crossover tool, crossing over tubing flow above the seal bore packer to annular flow below it. –– After rotating the crossover tool free from the seal bore packer, upward movement of the crossover tool unseals a concentric string (washpipe) inside the screen from the hookwall packer. Fluid treatments such as acids, clay stabilizers, and the gravel slurry itself can then be circulated down and circulated through the screen or squeezed into formation similar to common industry practices. –– After the gravel pack is complete, the crossover tool and concentric string are removed, and a seal assembly is run inside the seal bore packer for production.
The chief limitation of the system is the amount of rathole available in the well. The area below the producing zone must be long enough to accept the spent TCP gun assembly.
Resin-Coated Sand Slurries for Repair of Damaged Liners
Authors: Murphey J. R. , Roll D. L. , Wong L. 
Published: December 2007

Abstract
Resin-coated sand can be used to repair damaged slotted liner gravel packs without removing the liner from the well. Either concentric or coiled tubing can be used to perform the treatment, using a small workover rig. The well can be returned to production typically in 24 hours.
This repair technique has been used with success in the Gulf Coast and West Coast areas. Economy of the treatment makes it viable for wells that are too marginal to justify complete liner workovers.
This paper describes the features and the application of the system and reports field results of 12 jobs performed over intervals up to 300 ft.
Studies of the Steamdrive Process in Inclined Reservoirs
Authors: Doscher T. M. , Marinello S. 
Published: December 2007

Abstract
Scaled physical model studies of the steam drive process in dipping reservoirs containing very viscous crudes, tars and bitumens, have shown that economic oil steam ratios can be achieved by judicious management whereas such economic ratios cannot be achieved in horizontal reservoirs where the opportunity for gravity drainage is much reduced.
Modeling Fracture Permeability Around a Well During Depletion
Authors: Bakhtar K. , Barton N. R. , Rakop K. , Jones A. H. 
Published: December 2007

ABSTRACT
The normal closure behavior of fractures around a well during various stages of depletion has a major influence on the changes in fracture permeability and subsequent well production. Methods are described for providing a practical approach for obtaining fracture parameters to model these permeability changes. The parameters of interest include: i) the fracture roughness coefficient (JRCo), ii) the wall strength (JCSo), which can both be obtained from simple tests on cores, and iii) the overburden and horizontal stresses around the fracture. The transformation equations would then be applied to estimate the effective normal stress on the fracture plane. The model relates the fracture aperture to the effective normal stress and subsequently computes the resulting permeability for changes in pore pressure.
Geology and Hydrocarbon Occurrence of the Khuff Formation in Abu Dhabi, U.A.E.
Authors: El Bishlawy S. H. 
Published: December 2007

ABSTRACT
The Khuff Formation in Abu Dhabi consists mainly of a thick shallow marine sequence of limestone, dolomite and subordinate anhydrite of Late Permian to Early Triassic age. The formation average thickness is about 2800 ft. and shows remarkable lateral consistency in lithology and log response that allow its correlation and sub-division into four major lithostratigraphic units, each of which is characterised by a specific lithofacies or lithofacies association. The formation depth of burial ranges between 11800 ft. and 19800 ft. subsea.
The Khuff Formation is generally characterised by poor porosity and low matrix permeability. The porosity types are of primary and secondary origins and are controlled by original depositional facies, depth of burial and diagenesis. Fractures are common in the section and have a significant impact on enhancing the effective porosity and permeability.
Production from the Khuff Formation is mainly gas and condensate with a maximum condensate ratio of 10 BBL/MMSCF. The main gas component is methane which forms more than 75% of the total Khuff gas composition, however appreciable amounts of hydrogen sulphide, nitrogen and carbon dioxide were also recorded in some of the wells.
The source of the hydrocarbon gas in the Khuff Formation is not yet well defined; however two sources are postulated: the first is a pre-Khuff source which is probably the Silurian Shales and the second is an indigenous one.
On-Line Inspection of Offshore Pipelines
Authors: Shannon R. W. E. , Fitzgerald E. M. N. , Jackson L. 
Published: December 2007

Abstract
Pipeline networks worldwide, which can be measured Pipeline networks worldwide, which can be measured in hundreds of thousands of kilometres, represent major capital assets with enormous revenue-earning capacity and as such often figure significantly in a country's economy. Of particular economic and strategic importance are under sea pipelines which provide the critical link between production provide the critical link between production platform and shore terminal sometimes over long platform and shore terminal sometimes over long distances. Such lines often take supplies from a number of sources via gathering lines and this makes their long term value, as old fields are depleted and new ones discovered, extremely high. In general these lines have been operated for many years during which time the pipeline industry generally has experienced changes in design, construction and maintenance methods some of which reflect the fact that high pressure pipelines are subject to deterioration to some degree or other. The rate at which this occurs depends on numerous factors not least being the chemical composition of the product carried, which may determine any internal corrosive action, and the degree to which an external protective coating and cathodic protection can be proof against the environment protection can be proof against the environment including third party interference. Such factors combined with the relative inaccessibility of submarine pipelines means that cost effective maintenance methods are an important factor in their operation. More particularly such methods must be capable at any time of quantitatively describing the structural integrity of the pipeline. This can be achieved only by pressure pipeline. This can be achieved only by pressure testing or some form of non-destructive evaluation.
Pressure testing will continue to be essential to Pressure testing will continue to be essential to the pipeline industry as an effective means of commissioning new and modified installations. Its value lies in the fact that it will reveal, sometimes in a spectacular manner, all defects that are significant at the particular test level.
It is not however a very cheap or convenient method of subsequent periodic testing being somewhat disruptive in terms of product supply unless additional pipeline capacity and/or storage can be used to maintain supply for the duration of the test. Clearly such an approach represents a significant capital investment especially in the case of main off-shore supply lines and is unlikely to be economically justified. Neither is it a straightforward test, requiring strict attention to time-consuming stages of filling with water, testing and drying out. In addition the location and repair of small leaks occurring during test is difficult.
New Cathodic Protection System Design for Dubai Platforms
Authors: Evans S. 
Published: December 2007

ABSTRACT
New sacrificial anode protection criteria that were developed and tested by the Dubai Petroleum Company (DPC) have resulted in a 40 percent decrease in anode weight as compared to that required by conventionally accepted design. Derivation of the criteria are based on an analyses of extensive field results of potential surveys of seven DPC platforms that had conventional sacrificial anode protection systems. It was found that an initial platform current density of 310±20 milliampers per square meter of area exposed to seawater, resulted in polarization of the platform to −1 volt with respect to the silversilver chloride reference electrode. As a consequence of this high initial polarization, the electric current requirement for protection is significantly reduced. The new criteria were used in the design of Platform "JJ" which was installed in September 1982. Field results that include periodic potential surveys of Platform "JJ" will be presented and discussed.
Biodeterioration of Concrete Piling in the Arabian Gulf
Authors: Jadkowski T. K. , Wiltsie E. A. 
Published: December 2007

ABSTRACT
Concrete is one of the most widely used materials in marine construction because of its characteristic durability in sea environments. Recent inspection of concrete piles installed in the Arabian Gulf has revealed that concrete with high content of calcareous aggregate is susceptible to biodeterioration. Marine rock borers and sponges, which are common in areas where the seabed is composed of limestone rock, have been identified as the marine species responsible for the biodeterioration. Boring organisms pose a significant threat to concrete pile structural integrity. Boreholes deteriorate concrete and expose outer pile reinforcement to seawater.
This paper describes the causes and magnitude of biodeterioration of piles installed in the Arabian Gulf and presents design parameters and material specifications for the selected preventive repair system.
The Occurrence and Origin of Oil in Offshore Abu Dhabi
Authors: Hassan T. H. , Azer S. 
Published: December 2007

ABSTRACT
Offshore Abu Dhabi, an area of some 30000 sq. kms. (11,600 sq.miles) is one of the richest oil-bearing areas in the world. The oil occurs primarily in the Upper Jurassic carbonates of the Arab Formation and in the limestones of the Lower Cretaceous Thamama Group. Minor oil accumulations occur in the Middle Cretaceous Mishrif Formation and oil and gas/condensate in the Middle Jurassic Araej Formation. Geographically, the occurrence of oil in the Arab and Thamama appears to be controlled by the Hith Formation seal, immediately overlying the Arab Formation and the featheredge of which runs N-S in the centre of the area. Thus, oil in the Arab Formation occurs only in western offshore Abu Dhabi where the Hith is present, whilst the most important Thamama oil accumulations either straddle the Hith Edge or occur to east of it. There are however, Thamama oil fields to the west of the Hith edge. Two primary source rocks have been identified: (a) The Upper Jurassic Diyab Formation consisting of argillaceous limestone occurring in source facies in western offshore Abu Dhabi and considered to have sourced both the Arab and the Thamama oils and probably also the hydrocarbons of the Araej. (b) The Middle Cretaceous Shilaif Formation which sourced the oil in the Mishrif.
Generation of the Arab oil from the Diyab commenced late in the Late Cretaceous with migration taking place from south western part of the area and directed in a northerly direction. But in the central area, oil would not have been trapped in the Arab because of absence of the Hith Formation caprock but in the Thamama Group. It is likely that there was another source for the Thamama oil located to the east of offshore Abu Dhabi.
Although over much of Abu Dhabi, the Shilaif forms a good source rock, it is generally immature and the source of oil in Umm Addalkh and nearby areas was derived from the more deeply buried Shilaif in offshore Dubai.
Notes on the Uwainat Oil Rim Development, Maydan Mahzam and Bul Hanine Fields, Offshore Qatar
Authors: Hamam K. A. 
Published: December 2007

ABSTRACT
As a result of reservoir simulation studies of the Uwainat reservoirs (Maydan Mahzam and Bul Hanine Fields), drilling to the Uwainat oil rim target became very "tight" with a very limited vertical tolerance. To achieve drilling to the tight target requires a precise position of the well at the top of the Lower Arab IV reservoir (a reliable marker) and an accurate isochore of the Lower Arab IV – Uwainat.
The discussion shows that the level of accuracy needed in determining both the actual subsea well position and in constructing the depth contours of the reservoirs is extremely high.
Determination of Residual Oil Saturation With the Borehole Gravity Meter
Authors: Maute R. E. , Gournay L. S. 
Published: December 2007

ABSTRACT
Use of the borehole gravity meter (BHGM) to measure remaining oil saturation is a method new to the industry. The technique is described, and its applicability to Middle East reservoirs is discussed. Results of an extensive error analysis are presented.
The method, which we call log-produce-log, consists of running a base BHGM before significant production, and a later BHGM after production. The remaining oil saturation is computed from the difference of the two BHGM measured bulk densities.
The Middle East oil fields are ideal for application of this method. Porosities are high, crude is light, and connate water is dense (saline). The method is independent, for all practical purposes, of hole size, rugosity, number of casing strings, shale content, and acidization. The method also has a very large radius of investigation, 50 feet plus, which enables it to sense a far larger volume of the reservoir than any other method. As reservoirs are often heterogeneous in both porosity and fluid saturations, the remaining oil saturation thus determined would be more representative of the reservoir as a whole than any other technique.
The disadvantages of the method are the need for a base BHGM log prior to significant production from the zone of interest, and a poor vertical resolution of about 10 feet.
Results of a comprehensive and realistic error analysis are presented and show this technique as possibly the most accurate Sor method.
An Experimental Study of Techniques for Increasing Oil Recovery from Oil Reservoirs with Tar Barriers
Authors: Shamaldeen S. M. , Farouq Ali S. M. 
Published: December 2007

ABSTRACT
A number of major oil reservoirs in the Middle East have a tar barrier between the oil zone and the underlying water zone, with a strong bottom water drive. This investigation is aimed at oil recovery from such reservoirs. Specifically, it is intended to explore several recovery methods that could be used for increasing oil recovery from such reservoirs. As far as one can ascertain, little or no work has been published on this subject of vital importance in Saudi Arabia, Kuwait, and Iraq.
The present investigation was experimental in nature, utilizing several models, and a variety of recovery schemes. In all instances, three zones were initially set up in the models: a light oil zone on top, a water zone at the bottom, and a tar zone between the two. The thicknesses of the oil and tar zones were varied to cover a range of conditions. The bottom water zone was equipped with a water drive.
The different recovery techniques tested were: (i) injection of water into the oil zone (internal waterflood), without a bottom water drive, (ii) internal waterflood, with a bottom water drive, (iii) bottom water drive, (iv) injection of solvent into the tar zone, (v) injection of steam into (a) oil zone, (b) tar zone, and (c) water zone.
The results show that when waterflooding the oil zone, an important factor is the extent of communication between the water zone and the tar zone. Such communication can be established by use of solvents or steam, though such processes are admittedly inapplicable in some of the deeper formations. Once communication is attained, an internal waterflood can be very effective. With bottom drive alone, recovery was found to be low in view of water channelling and coning. Solvent injection runs showed that large volumes of a suitable solvent will have to be injected in order to obtain the necessary communication. Steam injection into the oil zone mitigated the benefits of a water drive. However, injection into the tar zone was effective both in promoting the bottom water drive, and also in recovering some of the tar, although this was not a primary objective. Injection into the bottom water zone was largely ineffective, since the heating of the overlying tar layer required very large volumes of steam.