bluuebunny/crossref_metadata_2025_split huggingface dataset:
Controlled Horizontal Drilling
Authors: Conti P. F. 
Published: December 2007

ABSTRACT
Very recently a conventional drilling assembly, directional Measurement While Drilling (MWD) and steerable system were used to drill the first successful horizontal well in Michigan's shallow Antrim gas zone. This essay is an analysis and evaluation of the technology applied and the procedure used to achieve a successful horizontal status. An explanation of the controlled drilling methods used to maintain a lateral status in the "Hot Zone" (anticipated high gas producing zone) is provided as well as case history information from the actual field operations.
An analysis of the economics of such a project is examined, along with a comparison of this well design versus straight hole drilling. The key issue in this project is the evaluation of the gas production, which is the prime economic factor that will determine the future of similar projects. The hypotheses offered by various operators were researched, and comparisons made to proven theories provide actual case history data for future lateral wells As more well information becomes available from current projects, it is anticipated that operators will plan new projects to maximize their production using their research and case history data to minimize their expenses.
The results of this lateral project are objectively presented so that specific conclusions may be drawn. Similar projects are highlighted to ensure that a fair and accurate evaluation can be derived from this project.
Laboratory Hot Waterfloods Prior to and Following Steamfloods
Authors: Shen C-W. 
Published: December 2007

ABSTRACT
Three-dimensional, high-pressure, physical models were used to determine the combined effects of hot waterflooding and steamflooding. The first case involved a hot waterflood prior to a steamflood; the second case was a study of a hot waterflood following a steamflood.
In this homogeneous sandpack model representing a one-quarter of 2-1/2 acre (1.0 ha), 88-ft (26.8 m) thick, confined five-spot pattern, the following were observed:
A steamflood following a hot waterflood recovered more oil than a steamflood alone. This increased recovery is explained by a change in the heat flow pattern in the formation. Instead of ascending to the upper region of the formation, the steam, following the established hot water channels, moved along the lower region of the formation and contacted additional oil. This improved the vertical conformance of steam injection. A hot waterflood following a steamflood produced little additional oil. The hot waterflood moved the oil that was bypassed by the steamflood, but a good portion was pushed into the depleted steamflooded zone and was not produced.
Gas/Oil Relative Permeability Calibration With Observed Time Drainage Performance
Authors: Shook R. A. 
Published: December 2007

ABSTRACT
An empirical technique to calibrate gas-oil relative permeability data to observed time drainage performance from repeat Compensated Neutron Log (CNL) data analysis has been developed. The technique will yield a unique estimate of endpoint residual oil saturations by observing the rate of time drainage after gas has moved through a logged interval. The technique will also establish the correct relationship between the kv/kh ratio and the exponent in the oil relative permeability expression (the Corey exponent) by noting the absolute oil saturation value existing at the onset of time drainage, as measured in a CNL logging program. By estimating the kv/kh ratio of a horizon by core work, statistical log interpretations, vertical pulse test, etc., the corresponding required oil exponent is determined. Thus, the endpoint residual oil saturation as well as the shape of the relative permeability curve can be calibrated based on the observed time drainage performance.
Some important observations made in the study are:
After the gas front has moved through an interval, the rate of oil drainage is independent of voidage rate and PV gas throughput. This is also true for a bypassed oil lens on top of a shale. The rate of drainage is insensitive to vertical locale, kv/kh ratio, and the relative permeability exponent. These parameters affect the absolute oil saturation values over time, but do not significantly impact the. rate of oil saturation change behind the gas front. After gas front passage, the rate of oil saturation change behind a gas front is most affected by the residual oil saturation to gas. A relationship between the kv/kh ratio and the oil relative permeability exponent exists that will correctly yield the oil saturation found at the onset of time drainage.
Drilling Aspects of the Deepest Well in California
Authors: Shultz S. M. , Schultz K. L. , Pageman R. C. 
Published: December 2007

ABSTRACT
On May 30, 1985, an Exploratory Well 934-29R was spudded in the Elk Hills Naval Petroleum Reserve #1 at Tupman, California. Bechtel Petroleum Operations, Inc. and the Department of Energy cooperated in a joint effort to drill a 25,000 foot well and determine whether or not hydrocarbons are present at the deeper depths. Several zones of interest had been drilled through when the well reached a final T.D. of 24,426 feet (Figure #1). This paper will reveal some of the more significant drilling technology used and also problems encountered while drilling the deepest well in California. Points to be covered will include the following:
Casing Design to Accommodate 5″ Drill Pipe LVT Oil Base Mud Diamond Bit Design Utilization of Turbodrills Cementing
Record-Setting Top-Drive Installation
Authors: de Haas R. 
Published: December 2007

ABSTRACT
Topdrives are found on rigs all over the world. Generally the procedure is, considering the amount of work to be done, to take the rig into a shipyard and do the job there and depending on which modifications are required, this takes between two and four weeks.
When a topdrive had to be installed on the "Neddrill 3", a cantilevered jack-up of the CJ46 design with a 147' U.I.E. derrick, the required time was not available. It was decided to install the topdrive and continue to be operational; a major task for management, engineers and rigcrew.
Wet Gas Flow Measurement
Authors: Nederveen N. , Washington G. V. , Batstra F. H. 
Published: December 2007

Abstract
Venturi meters, used in combination with relationships published for orifice plates to correct for wetness, can accurately meter wet gas. This allows separators to be omitted from gas field developments where they were used only to remove entrained liquid before the gas was metered. Vortex meters have also been investigated but they do not give predictable readings. A calibration technique based on the tracer dilution technique using inert gases has been developed to calibrate wet-gas meters.
Potential Geomechanics Problems Resulting From Closely Spaced Storage Wells in Dome Salt
Authors: Ratigan J. L. , DeVries K. L. 
Published: December 2007

Abstract
Limited area often requires closely spaced solution mined hydrocarbron storage wells. The technical basis for spacing regulations is often unclear. The analysis presented in this paper suggests that web thicknesses between adjacent wells can be significantly less than required by state rules or Strategic Petroleum Reserve design guidelines.
The Analysis of Gas Well Test Data Distorted by Wellbore Storage Using an Explicit Deconvolution Method
Authors: Blasingame T. A. , Johnston J. L. , Lee W. J. , Raghavan R. 
Published: December 2007

Abstract
This paper presents a new method for analyzing gas well test data distorted by wellbore storage. The method that we propose in this paper is an explicit deconvolution method which is independent of the reservoir model. As is well known, the deconvolution procedure corrects test data influenced by wellbore storage and yields the pressure profile that would have existed had the afterflow rate been zero. Deconvolved data may then be analyzed using conventional semilog and type curve techniques.
This new deconvolution method has an explicit solution; i.e., a single formula corrects for the wellbore storage effect using measured bottomhole pressure and sandface flowrate. Previously introduced methods are tedious and difficult to apply. This method is much faster, gives equitable accuracy, and is easy to use. In the event the sandface flowrate is not measured, methods to estimate the sandface rate using our proposed wellbore material balance equation are presented.
The method given here is simple enough to be used in hand calculations; algorithms to apply this method are outlined in this paper.
A New Stimulation Technique for Acid-Sensitive Formations
Authors: Peters F. W. , Cooper R. E. 
Published: December 2007

ABSTRACT
A new technique has been developed to stimulate heavily damaged, high-permeability wells that cannot be successfully acidized. Many sandstone producing formations in the ASIA-PACIFIC region fall into this category, for a variety of reasons.
The technique restores productivity in damaged wells by providing a very short, highly conductive fracture through the damaged area around the well bore. Given adequate fracture conductivity, combined with enough length to ensure the fracture penetrates virgin formation permeability, production can be restored to levels greater than a well's natural capacity to produce in its undamaged state.
This paper includes a discussion of some of the well conditions that can indicate a good candidate for the new application, as well as guidelines for designing the treatments. The technique is not easily modeled with conventional fracture simulators, but simple volumetric determinations have been used successfully to select effective treatment sizes. Two case histories are documented, plus the design considerations for two additional cases. The examples include applications for a variety of well conditions.
Performance Testing of Jar Accelerators
Authors: Kyllingstad A. , Slørdal L. H. 
Published: December 2007

ABSTRACT
This paper presents results from a test program on jars and jar accelerators. Ten different accelerators in the range of 6.25" OD to 8" OD have been tested in a horizontal jarring rig built especially for this investigation. The test program comprises both single tool tests and full jarring tests where accelerator's are tested together with jars. Slow loading and deloading of the accelerators has revealed great differences in performance. In general hysteresis loss is higher than expected and efficiency is lower than expected from suppliers claims. Temperature tests with heated tools have shown that the temperature has a large effect, especially for accelerators using a compressible fluid as spring elements. Finally, measurements during full jarring tests where the accelerators are deloaded very fast, clearly show that dynamic friction losses are quite significant for some of the tools. The test results and their applications to real field jarring are discussed.
The Seismic Method A Useful Tool In Underground Gas Storage Exploration
Authors: Engquist Bruce E. , Reinerio E.D. 
Published: December 2007

1967 REGION X MEETING SOCIETY OF PETROLEUM ENGINEERS AMERICAN INSTITUTE OF MINING and METALLURGICAL ENGINEERS SEPTEMBER 9, 1967 EVANSVILLE, INDIANA

Abstract
The exploration for subsurface structures in northern Illinois suitable for the storage of natural gas is often handicapped by a lack of geologic data. Seismics is a geophysical tool that can serve u an aid to an exploratory drilling program. The purpose of this paper is twofold: first, it will briefly explain the fundamentals of seismics; and second, it will outline the details of an actual exploratory seismic survey. The geological interpretation was inadequate due to a limited density and distribution of data. The geophysical interpretation was also inadequate until correct velocity was applied to the measured time to obtain depth. Cooperation of the geologist and the geophysicist is essential to insure the correct integration of all data. In this manner, the final geologic evaluation of an area will have encompassed all available data in the search for subsurface structures.

Introduction
The area of exploration of the Northern Illinois Gas Company for gas storage structures is essentially limited to the northern one-third of the state. This is north of the Illinois Basin and geologic data from petroleum exploration is extremely sparse. All operating storage fields of Northern Illinois Gas Company are aquifers, barren of hydrocarbons, with a natural water drive.
Drilling Kick Statistics
Authors: Wylie W. W. , Visram A. S. 
Published: December 2007

ABSTRACT
A drilling occurrence is a non-routine event that may be encountered while drilling a well such as a water flow, lost circulation, a kick or a blowout. In Alberta information on occurrences are reported on the drilling tour reports which are submitted to the Energy Resources Conservation Board (ERCB), the Government regulatory body. Drilling information is extracted and stored on an integrated database. The drilling ocurrences and specifically the kicks and blowouts, for a ten year period (1979-1988) have been analyzed to determine trends and frequency rates. The kick information extracted included the well identifier, the operation in progress, the occurrence date, the occurrence depth, the well's total depth, the finished drilling date, and the type of well (development or exploratory).
The analysis indicated that the risk of a kick is significantly greater for exploratory wells than for development wells, and also increases significantly for deeper wells. The analysis of the operation in progress at the time of the kick indicates similar rates for both development and exploratory wells, and that failure to keep the hole full is the major cause of kicks with drilling with inadequate density fluid a close second.
Technique to Assess Directly Make-Up Contact Stress Inside Tubular Connections
Authors: Slack M. W. , Salkin H. , Langer F. H. 
Published: December 2007

ABSTRACT
In premium oilfield tubular connections, control of make-up prestress or contact pressure on the seal is critical to structural and leakage integrity. Current technology relies on indirect methods, such as torque-turns and short term internal gas pressure tests, for evaluation of this contact pressure.
This paper describes a new technology that directly measures contact pressure between mating solid parts. This technology uses an ultrasonic reflection amplitude pressure (URAP) correlation, and is based on the reflection characteristics of elastic waves from thin films, such that the thread compound 'squeeze film' functions as a quick, safe and non-intrusive stress gauge.
A brief treatment of the physics used to explain the measurement is given with empirical correlations of the URAP measurement to contact pressure. Development and testing of a prototype rig floor tool with results from laboratory and field trials are presented to demonstrate the feasibility of applying this technology to measure the actual connection prestress in real time. This data clearly demonstrates the potential for URAP to become a reliable technique for quality control and quality assurance in the make-up of premium connections.
Wellbore Stability Analysis: A Review of Current Methods of Analysis and Their Field Application
Authors: McLean M. R. , Addis M. A. 
Published: December 2007

ABSTRACT
Hole problems during the drilling phase of operations are often the consequence of mechanical wellbore instability. This leads to higher than necessary drilling costs. A number of analytical and numerical models are available for the diagnosis and prediction of wellbore instability; this paper reviews the merits and pitfalls of applying these models to field situations. Attention is focused on the peak-strength criterion and constitutive behaviour model. Anomalies from the incorporation of the intermediate principal stress into peak-strength criteria are highlighted. To illustrate the reliability of a number of models, their predictions are compared with laboratory results, and with a case history of a horizontal well drilled in the Cyrus Field in the North Sea.
The Application of "Mechanical" Borehole Stability Theory to Development Well Planning
Authors: Fleming N. H. , Ronaldi R. , Bruce S. , Haryanto J. 
Published: December 2007

ABSTRACT
Shales are widely blamed for drilling problems. Such problems are frequently attributed to mud/shale chemical interaction, abnormal pore fluid pressures and excessive overburden or tectonic earth stresses. Problems experienced include 'lost time' due to tight hole, sloughing, and even loss of the hole. This paper attempts to evaluate the practical application of mechanical stability studies to directional well planning and emphasizes the importance of a 'combined approach' when tackling specific shales, where problem severity is frequently best understood in terms of both borehole stress and chemistry.
An analytical technique has been developed, which utilizes wireline sonic, bulk density and gamma ray data from offset wells, to estimate the mechanical integrity of the wellbore with depth and hence the mud weights required to support the borehole wall without fracturing weaker beds. Increasing hole inclination usually narrows the choice of safe operating mud weights. The log was evaluated in CONOCO's Ikan Pari development field in Block 'B', South China Sea Indonesia, where shale 'bridging' and 'sloughing' had plagued earlier drilling campaigns. These recent efforts to identify the causes of hole problems in Block 'B' demonstrate the cost saving potential of stability studies to development well planning and should be applicable to many other areas. A stability log from the vertical well in an offshore development field can be re-run at the planned well trajectories; this can provide valuable input to casing seat and mud weight selection, cement program design, fracture gradient calculation, drilling procedures through problem sections and directional well planning, (particularly high angle profiles).
Design and Development of High-Strength, Sour Service Drillpipe
Authors: Shivers R. M. , Greer J. B. , Smith J. E. 
Published: December 2007

Abstract
Drillpipe for deep, sour, highly deviated, abnormally pressured Norphlet wells in the Mobile Bay Area requires tensile and torsional strength in excess of conventional API Grade X-95 drillpipe with NC50 tool joints. It was decided to construct a drillstring from 105,000 psi [724 MPa] minimum yield strength steels with optimum chemical composition for welding, toughness, and resistance to H2S exposure. Design load requirements led to the selection of a tool joint with a secondary torque shoulder. Quality assurance testing indicated that an SSC resistant, Grade CG-105 grade drillpipe is feasible to manufacture.
Studies of Fractures Induced During Cyclic Steam Injection
Authors: Reis J. C. 
Published: December 2007

Abstract
Induced fracturing during cyclic steam injection was studied in two heavy oil reservoirs in California. In a shallow, unconsolidated sandy-conglomerate, steam induced fracturing was chaotic, with multiple events occurring over a period of days. Predominantly horizontal fractures appeared to open and close in various locations and at various times. Not all of the temperature events observed in observation wells that suggested fractures correlated with changes in the injectichon pressure. No model for steam flow in this reservoir could be developed. In a deeper, less permeable, more consolidated formation, two vertical fractures simultaneously opened along the wellbore at different depths at the start of injection and remained open during injection and production. The fractures were co-planar and were separated by a shaly interval. Multiple fracturing events were not observed. A simple thermal conduction model was developed that successfully matched the measured data and allowed the effective reservoir permeability to be estimated.
Detailed Mapping of Fluvial Sand Bodies Improves Perforating Strategy at Kern River Field
Authors: Brelih D. A. , Kodl E. J. 
Published: December 2007

ABSTRACT
Detailed geologic mapping can greatly enhance perforating and production strategies in a complex field under active steamflood. Some of the smaller, thinner sand bodies, overlooked because of discontinuity, may actually produce significant amounts of oil if their development is wisely planned. This involves identification of the wells in the downdip locations and/or in the thickest parts of the structure and perforating when preheat from an adjacent steamflood is realized.
Variations in Thermal Properties with Lithology in the San Joaquin Valley, California
Authors: Reis J. C. 
Published: December 2007

Abstract
Geothermal gradients and thermal conductivities were measured in three oil-saturated formations having different lithologies at one location in the southern San Joaquin Valley, California. The three lithologies in order of increasing depth were a sandy conglomerate, diatomite, and porcelanite, respectively.
The geothermal gradients were measured with arrays of thermocouples in dry observation wells prior to steam injection in the area. The measured gradients for the three lithologies were 1.8, 5.8, and 2.3 °F/100 ft (33, 106, and 42 mK/m), respectively. The geothermal gradient through the sandy conglomerate and the porcelanite are consistent with published valued for this area (Sass, J.H., Galanis, S.P., Jr., and Munroe, R.J.: Measurement of Heat Flow by a Downhole Probe Technique in the San Joaquin Valley, California (1982) USGS Open-File Report 82-819), but the gradient through the diatomite is significantly higher.
Thermal conductivities of these formations were measured on core taken from nearby wells. Because thermal conductivity varies with porosity and oil saturation, core samples were selected for each lithology that had values equal to the average of their respective formations. The thermal conductivities were measured using the steady-state, divided-bar method at 150 and 300 °F (66 and 149 °C). The measured values for the sandy conglomerate at the low and high temperatures values were 0.71 and 0.77 btu/(hr-ft2 -°F/ft) (1.22 and 1.33 W/m-K), respectively. The values for the diatomite were 0.35 and 0.51 Btu/(hr-ft2-°F/ft) (0.61 and 0.88 W/m-K), respectively, while the values for the porcelanite were 0.63 and 0.67 Btu/(hr-ft2-°F/ft) (1.09 and 1.16 W/m-K), respectively. The thermal conductivity of the diatomite was considerably lower and its temperature dependence was greater than that of the other formations. These data are consistent with published values for other sedimentary rocks (Anand, J., Somerton, W.H., and Gomaa, E.: Predicting Thermal Conductivities of Formation from Other Known Properties, Soc. Pet. Engr. J. (1973) Vol. 13, No. 5, pp. 267-273).
Formation Damage Prevention and Adsorption Studies of Nonionic Surfactants in Sandstone Reservoirs
Authors: Paktinat J. , Dunlap D. D. 
Published: December 2007

Abstract
The adsorption of chemical additives used in conjunction with matrix acid systems presents an obstacle to improved stimulation performance. The primary purpose of surfactants used in acid treatments is to reduce acid surface tension and contact angle and prevent acid/formation fluid emulsion. However, many of these chemicals adsorb rapidly in sandstone media, reducing their effectiveness in the formation.
This study describes the laboratory and field investigation of various surfactant components and their adsorption properties in sandstone. A six foot long sandstone core apparatus provides the primary means for laboratory investigation, Various surfactant constituents such as ethoxylated nonyl phenols and linear alcohols are investigated for their adsorption properties. This data may be used to develop chemical additive systems which optimize chemical penetration in a sandstone formation.
The primary results of this study include:
Improvement in penetration of surfactants when linear ethoxylated alcohol is used rather than commonly used nonyl phenol ethoxylates. The C12-C13 alcohol with ethylene oxide ratios of 9 to 15 moles shows to be the most effective for formation damage prevention.