bluuebunny/crossref_metadata_2025_split huggingface dataset:
Performance of the Twofreds CO2 Injection Project
Authors: Kirkpatrick R. K. , Flanders W. A. , DePauw R. M. 
Published: December 2007

Abstract
The Twofreds (Delaware) Field, located in Loving, Reeves, and Ward Counties, Texas, is operated by HNG Fossil Fuels Company and has been under continuous CO2 injection since February, 1974. The field was nearing its economic limit under waterflooding when the CO2 project was initiated. In the 11 years since tertiary injection began, total field oil production has been increased from 170 bbl/D (27.0 m3/d) to over 920 bbl/D (146 m3/d). Tertiary oil recovery to date has been over 2.5 × 106 barrels (0.397 × 106 m3) of oil. This mature, commercial-scale project offers a unique opportunity for the evaluation of long-term effects of practical CO2 operations. The field currently produces 923 bbl/D (147 m3/d) of oil at a gas-oil ratio of 3,240 cu ft/bbl (577 m3/m3), 1,755 bbl/D (279 m3/d) of water, and has cumulatively produced 11.2 × 106 barrels (1.78 × 106 m3) of oil and 16.9 × 106 barrels (2.69 × 106 m3) of water since discovery in 1957.
The Twofreds (Delaware) Field produced under primary recovery from January, 1957 until January, 1963 when it became the first unitized water injection project in the Delaware Basin.1 In February, 1974, Twofreds became the first field-scale tertiary CO2 injection project in a sandstone formation in Texas. The majority of the field (98.6%) had been purchased for tertiary purposes by HNG Fossil Fuels Company, Murphy Oil USA, Inc. and RGS (Ritchie, Gerard & Stanberry). Atlantic Richfield Company (ARCO), with the remaining 1.4%, was the only original owner that elected to maintain their interest in the field, and joined in the operation. Carbon dioxide for the Twofreds Field is obtained from Intratex
Gas Company's MiVida Gas Processing Plant located 9.64 (15.5 km) miles from the field. Exhaust gas injection was initiated in October, 1980 to supplement the CO2 injection. This additional injection made possible the expansion of the project to include the entire field.
Performance Forecasting and Economic Evaluation of a Deeply Buried Coalbed Methane Reservoir in the San Juan Basin
Authors: Jones A. H. , Bush D. D. , Kelkar S. M. , Ahmed U. , Bell G. J. 
Published: December 2007

ABSTRACT
A program was undertaken by Terra Tek, Inc. of Salt Lake City, Utah, in cooperation with the Tiffany Gas Company of Farmington, New Mexico, to evaluate the recovery of hydrocarbon gas from the Fruitland Formation coal within the San Juan Basin in Southwest Colorado. The target coal was distributed through six seams at depths between 3062 and 3112 feet; and net coal thickness was 25 feet.
Well tests were performed to determine total permeability for the fully saturated reservoir, skin factor and initial reservoir pressure. Core tests on coal samples determined the original adsorbed gas content, the adsorption isotherms, porosity, capillary pressure, and relative permeabilities. These parameters were used as input data to a computer code to history match the water/gas production for both the underreamed and stimulated well. Predicted productions were used in economic analysis. After the well was underreamed, gas production was uneconomic. Following hydraulic fracture stimulation, economic gas flow was achieved.
A Leading Index of Drilling Activity
Authors: Buell R. S. , Maurer R. A. 
Published: December 2007

ABSTRACT
A five-component composite leading index of rotary drilling activity for the last thirty-six years is presented. Economic and technical justification are presented showing why each particular component of the leading index should be expected to lead drilling activity. The leading index has consistently led drilling cycle peaks and troughs by seven months over the thirty-six years studied.
Statistical Method for the Determination of Zone Boundaries Using Well Log Data
Authors: Dharmawardhana H. P. K. , Keller G. V. 
Published: December 2007

ABSTRACT
The proposed method provides a physically meaningful solution to the division of well logs into naturally occurring zones using the variability of well log parameters. The zone boundaries are defined in such a way that the variance of the given parameters within zones is minimized and the variance of the said parameters between zones is maximized. The above criterion is in accordance with the definition of the zone and zone boundaries where homogeneity is preserved within zone and is interrupted at the boundaries. In Gill's (1970) approach, a prior knowledge of the number of zones is needed to establish the zone and zone boundaries, where as present work does not call for the same. In other words, the zone and zone boundaries are controlled automatically by the preset termination conditions. Pickett and Souder's (1972) approach consists of searching for extrema in the derivative of the amplitude with respect to depth which resulted in picking the inflection points as boundaries. Since the points of inflection are not the absolute zone boundaries, this technique over estimated the number of zones. The present work has overcome this difficulty by looking at the variability of the well log parameters.
Cement Evaluation in the Gulf of Thailand
Authors: Perry Conrad , Henry Ken 
Published: December 2007

ABSTRACT
Union Oil Company of Thailand, a subsidiary of Unocal Corporation, has developed major natural gas and condensate reserves in the Gulf of Thailand, approximately 130 miles south of Bangkok. Union, as operator on behalf of its co-ventures Southeast Asia Petroleum Exploration Company and Mitsui Oil Exploration Company Limited, has developed four offshore fields which are currently capable of producing 450 million cubic feet of gas and 20,000 barrels of condensate per day. Natural gas from these fields supply 30 percent of Thailand's energy requirements.
The Gulf of Thailand provides a challenging environment for primary cementing and cement evaluation. Most wells are directionally drilled, deviated up to 60°, with an average total depth of 10,500', and have a bottom hole temperature of 320° F or greater. Oil base mud is used routinely for drilling, and requires consideration when planning the cementing operation. Evaluation of the cementing operation is critical, as zones to be perforated are always in close proximity to water, either as gas water contacts or permeable water sands.
In order to obtain a good evaluation of cement quality and distribution, the Cement Evaluation Tool (CET) has been used on over 30 wells to complement and improve the information obtained from the conventional Cement Bond Log (CBL). This paper shows examples of both CBL and CET on several wells in the Gulf of Thailand. Recently, the CET and CBL have been recorded simultaneously on one trip in the well, enabling a special presentation which displays the data on one film.
These practical examples show how gas migration and channelling can be identified, in addition to the effects of casing centralization. The accuracy and resolution of the CET acoustic caliper for use in casing inspection is shown. Examples show the importance of the total circumferential cement distribution data provided by the CET in determination of zone isolation. The lack of microannulus effect on the CET is presented, along with recommendations on how to obtain good quality log data.
Well Test Interpretation in Faulted Reservoirs
Authors: Kabir C S , Kucuk F , Gomez-Angulo J 
Published: December 2007

ABSTRACT
Well test analysis for a well adjacent to a no-flow boundary or a fault presents a significant interpretation challenge. The interpretation difficulty stems from the fact that early-time skin- and storage-dominated period and the subsequent boundary-dominated period obscure the middle-time data. Consequently, conventional semilog or type-curve analyses are difficult to perform. Because of dominating influence of inner and outer boundary conditions, an appropriate interpretation model is necessary for the estimation of reservoir parameters.
This work presents analytical models to analyze data for a well located at various distances from a fault, having wellbore storage and skin effects. The models are cast in the familiar graphical format with dimensionless variables – known as type curves. These type curves exhibit a different character than those of Gringarten et al for an infinite-acting reservoir. Both constant wellbore storage and exponential decline storage cases are considered in this work. The new type curves offer the potential for reservoir parameter estimation of permeability, skin and wellbore storage coefficient. Additionally, the distance to a fault could be estimated.
Application of the new type curves, using an automated matching technique, is demonstrated through field examples. Data from several wells located in highly faulted off-shore gas and oil reservoirs in south-east Asia are used for the purpose. Difficulty of analyzing the data using conventional semilog analysis is also shown in this work. This study further shows that only the very early-time data (&lt;10 minutes) that are affected by the wellbore storage effect are amenable to pressure-rate-time or convolution analysis, obeying the radial-cylindrical flow model.
Hydrocarbon Miscible Flood: Field Facility Design
Authors: Verma K. , Giesbrecht P. 
Published: December 2007

ABSTRACT
This paper summarizes the design, selection, installation and operational aspects of hydrocarbon miscible flood field facilities. Field facilities discussed include solvent and gas, fresh and produced water injection pipelines, double block and bleed system, and injection wellhead. The piping design for high pressure injection system is described to explain the economics of selection of high grade pipe.
In a cyclic miscible injection system, hydrate formation is the main operational problem. This paper presents the rationale for selection of the unique design of double block and bleed system. The simplicity of this design has reduced operating costs. The techniques involved in switching the cycles from solvent injection to water and vice versa are described.
Field facilities pressure testing has always been an outstanding question, especially for miscible injection lines. Water, gas and methanol as test media are evaluated.
ESP Cable Insulation: Selection for Performance
Authors: Schultz R. E. , MacKenzie B. T. , Marefat K. 
Published: December 2007

Abstract
Electrical cable for submersible pumping systems must be of high quality and reliability. Because of this, careful selection must be made of materials which will optimize performance in a wet electrically stressed environment. Polypropylene is the insulation used in lower temperature cables which is a major part of this cable market. Over the past eight years a major engineering effort has been placed on the evaluation of polypropylene resins and their wet electrical properties. Test methods were selected which distinguish between resins based on long term electrical stability. Properties of most extrusion grade resins available together with some experimental resins will be reviewed. Dielectric breakdown, insulation resistance, dielectric constant and power factor all versus time will be presented. The data will demonstrate the need for long term evaluations prior to the selection of a polypropylene insulation for ESP cable applications.
Jackup Drilling Unit, Substructure Skid-Off System for Fixed Platforms
Authors: Cochran T. J. 
Published: December 2007

ABSTRACT
One of the perennial problems for operators of fixed offshore production platforms has been the consider-expense involved in the drilling of additional wells or working over wells that are out of the thirty-five to forty-five foot reach of "standard" cantilever jackup rigs.
These jobs usually require the use of self contained platform drilling rigs.
The installation of a platform rig becomes quite expensive when the costs for deck barges, tugs, derrick barges and "rig up/rig down" time are all considered. In fact, the costs are great enough that many operators will forego or delay the drilling of an additional well or performing well maintenance because of the initial expenses involved in using a platform rig.
Conducting Effective Drills on MODU's
Authors: Taft D. G. , Carroll K. L. , Major R. A. , Marucci T. F. 
Published: December 2007

Abstract
Several of the recent MODU accident investigations have identified a need to improve emergency drills on mobile rigs. Conducting effective drills can be an important part of a training program to teach crews to deal with emergency situations. The authors have identified several key elements that appear to contribute to effective drills based on their observation of drills on many (about 40) MODUs. These elements are planning, conducting and reviewing a drill. Management must take an active role in these areas if the onboard drills are to be effective. Planning includes selecting appropriate drill topics for fire and abandon rig drills to ensure the crew gets as much benefit as possible out of drills. This paper discusses several ways to get the crew and management actively involved in planning and reviewing the weekly fire and abandon rig drills as well as other types of emergency drills.
Almost every rig surveyed by the authors could have benefited from improved fire and abandon rig drills. In actual emergencies, crews that have been trained through the use of realistic drills have responded better than crews that participated in cursory drills. Improving drill performance will assist virtually any MODU crew if it should ever encounter an emergency situation.
Case History: Designing and Implementing the Operations for Drilling in the Navarin Basin, Alaskan Bering Sea
Authors: Zaremba H. B. , Millheim K. K. , Boykin G. F. 
Published: December 2007

ABSTRACT
The Navarin Basin, located in the Alaskan Bering Sea, is the approximate size of the state of Louisiana. In 1984, industry paid over $681 million for leases in the Navarin Basin. Amoco Production Company, along with two other companies, decided to explore parts of the Basin in 1985 to evaluate its hydrocarbon potential.
Because of ice encroachment and associated environmental concerns, the drilling window for most of the Navarin Basin is between June and December. Amoco's strategy was to drill four to six wells starting in June (historically the time the ice regresses).
This paper presents how a systems-oriented approach was used to plan, prepare for drilling and drill five wells by mid-November 1985. This paper will show how the project objectives and environment led to the design of the "wareship concept" to support the drilling of five wells without one day being lost waiting on materials or personnel. The paper will present the first major use of Amoco's "Critical drilling Facility" concept to plan, prepare and drill the Navarin wells.
The paper will show how two drilling rigs, a wareship, tanker, four workboats, two standby boats, three helicopters, a staging base in St. Paul and a secondary support base in Dutch Harbor was controlled by the Anchorage Navarin Operations Center using the Tulsa-based Critical Drilling Facility. This was all made possible by the advanced systems technology, including a sophisticated satellite communications system and a project-oriented methodology.
This paper will present the drilling system design, implementation, and results. This includes the design and use of a potassium lime mud system and the optimization of the solids control system on each drilling machine. Included results will show that the designed drilling system achieved all drilling objectives and had a significant impact on the success of the Navarin project.
Turbine Performance in Texas Offshore Waters
Authors: Bethke M. E. 
Published: December 2007

ABSTRACT
The paper highlights twenty turbine/diamond bit runs attempted recently in Texas Federal Offshore waters. The runs were attempted most often in directional wells in the Mustang Island Area. The concept has been applied in 12-1/4″, 10-5/8″, 8-1/2″, and 6-1/2″ holes. Successful results have been obtained in 10-5/8″ hole and smaller, when bit design and turbine performance is optimized with proper advance planning and area experience.
Equipment descriptions, performance, and directional results using conventional and "steerable" turbines will be reviewed. Field data will be presented and compared with offset conventional rotary bit runs.
Automation of Solids Control Systems
Authors: Ardrey W. E. , Nix G. L. , Wright J. P. 
Published: December 2007

ABSTRACT
Data acquisition of well/rig data during the drilling operation has evolved from simple mechanical devices to sophisticated microprocessor driven devices. Instrumentation in the form of computerized data acquisition in the oil field have historically been used to archive drilling parameters and mud data. An indication of the current or real time condition of drilling rig parameters is generally displayed as well.
Likewise, solids control equipment found on drilling operations has been commonplace for decades. Generally the interpretation of solids equipment efficiency and operation is left to the crew or operator. The cost savings derived by proper use of solids control equipment is directly affected by its proper utilization.1,2
The scope of this paper is to illustrate that continuous surveillance of the solids control equipment by a data acquisition system can provide the most effective utilization of that equipment and thus affect (and help reduce) operational costs.
A Method of Modeling the Directional Behavior of Bottomhole Assemblies Including Those With Bent Subs and Downhole Motors
Authors: Brett J. F. , Gray J. A. , Bell R. K. , Dunbar M. E. 
Published: December 2007

ABSTRACT
This paper presents an analytical model that has successfully predicted the inclination directional behavior of rotary drilling bottomhole assemblies, including assemblies that contain bent subs and downhole motors. The model has been installed as part of the Engineering Simulator for Drilling (ESD), and combines the effects on directional behavior of bottomhole assembly configuration, hole geometry, rock drillability, bit type and operating parameters such as bit hydraulics, weight-on-bit and rotary speed. The model combines previous work dealing with bottomhole assembly analysis and bit mechanics (including side-cutting behavior), with original work defining the manner by which bits directionally penetrate.
The model's computation scheme depends on a microcoded version of a finite element bottomhole assembly behavior program running on an array processor. The system provides solutions of the finite element routine every one to six seconds. Solutions are required at this frequency in order to obtain stable directional predictions at 30 times faster than real time.
The paper also shows that comparisons of the model results with field data are good in areas where formation affects are benign. Comparisons of model predictions with field results in areas of significant formation directional affects are also shown. These comparisons are useful in quantifying the effect of the dip and strike on directional behavior, and in defining areas where future work is needed.
API's Q1 and 6A Initiative: Critical Issues, From a Manufacturer's Viewpoint
Authors: Holm R. A. 
Published: December 2007

Abstract
This paper discusses critical issues regarding API's recent Q1 and 6A initiative. It presents a manufacturer's viewpoint on the current efforts of API, producers, and manufacturers to self-regulate design and quality in our industry. FMC encourages adoption of these practical consensus standards to better assure the safety and reliability of wellhead equipment.
A Technique for Accurate Bit Programming and Drilling Performance Optimization
Authors: Simmons E. L. 
Published: December 2007

ABSTRACT
The dilemma of improving drilling rate and efficiency through the use of various optimization techniques has been the center of research and debate for many years. Both the well planner and the drilling supervisor in the field are acutely aware of the positive affects of optimized drilling on wellbore stability, the reduction in overall drilling costs, and the ultimate usefulness or production of the well.
The purpose of this paper is to illustrate a technique for synergistically coupling several optimization parameters, namely optimum hydraulics, weight on the bit and bit rotation, in order to achieve a higher degree of drilling efficiency. Formation drillability and bit type selection are brought out and integrated with a generally accepted drilling rate equation.
The result, is a technique that provides the engineer involved in well planning, with a reasonable procedure for analyzing previous offset operations and subsequently predicting, with reasonable reliability, those parameters and their magnitudes required for drilling optimization on the well he is planning. Also, by employing a modification this technique during drilling operations, the supervisor on location can constantly be "fine tuning" certain drilling parameters in order to achieve optimum drilling performance.
Fundamentally the technique involves generally accepted procedures which are merely coupled to form a synergistic system. It is simple enough to be employed in the field and yet can be thorough and detailed enough to provide the engineer in the office with the tools to perform accurate and timely well planning, based upon reliable offset well data.
Comparison of Environmentally Acceptable Materials with Diesel Oil for Drilling Mud Lubricity and Spotting Fluid Formulations
Authors: Kercheville J. D. , Hinds A. A. , Clements W. R. 
Published: December 2007

ABSTRACT
A contemporary state of the arts study is presented comparing environmentally acceptable lubricants with diesel oil-based products for water based drilling fluids. Diesel oil has been the base that has served the industry so well for many years. Its use is now severely limited in many areas if not completely banned.
Functions of a lubricant in drilling mud are to lubricate the drill string and prevent differential sticking. These laboratory studies show a range of lubricity values for various drilling mud compositions which demonstrate the ability of the fluid to wet or lubricate the drill string. They also show the ability of compositions formulated as spotting fluids to release stuck pipe in lab simulated sticking situations. Different types of lab-prepared and field muds were selected for the tests.
Lubricity coefficients were used to measure the lubricating properties of the fluids. The coefficients are on a scale of 0.0 to 0.50 and most drilling fluids containing diesel oil or environmentally acceptable oils were found to vary no more than about 15 to 20%.
The studies point out that there are environmentally safe materials that can be effectively used in place of diesel oil for lubricity and spotting fluid formulations. Some of these blends disperse more readily in muds than diesel oil thereby imparting better lubricating qualities and more resistance to sticking.
The Effect of Various Polymers and Salts on Borehole and Cutting Stability in Water-Base Shale Drilling Fluids
Authors: Bol G. M. 
Published: December 2007

ABSTRACT
Shale hydration tests have been carried out at confining pressures, ranging from 0 to 350 bar. The results show a high swelling pressure, without significant expansion, at high confining pressure and a large expansion without swelling pressure in the unconfined situation. It is also shown that different salts have different effects on swelling and that the effect of mud additives other than salts is negligible. The test results indicate that, for the shales tested, water structure modification and not ion exchange is principally responsible for the inhibitive effect of salts.
In addition, borehole erosion and cutting disintegration tests have been carried out. The results of these tests show a significant effect of various polymeric mud additives in terms of cohesion.