Bruton G.A.,Chesapeake Operating Inc. |
Talkington J.,Chesapeake Operating Inc. |
Desai P.,Schlumberger |
Swadi S.,Schlumberger |
SPE/IADC Drilling Conference, Proceedings | Year: 2013
The Granite Wash formation in Beckham County, Oklahoma and surrounding areas presents a number of unique challenges in drilling the build section from a vertical openhole to form a horizontal lateral in the productive zone. The formation is hard and abrasive and it is difficult to anticipate rock properties downhole from one well to the next. The erratic nature of the formation results in unpredictable performance by the steerable drilling assembly and drill bits particularly in the build section below 12,000 ft. In most cases, the target build rates are not achieved forcing multiple trips and undesirable cost overruns. To remedy the issue, an innovative drilling system was developed which provides a dependable kick-off ramp and a firm beginning in initiating the build section without having to rely on the drilling BHA's fulcrum point. From the bottom, the drilling system consists of hydraulically set openhole anchor, a whipstock, an impregnated drill bit mechanically attached to the top of the whipstock, a double bend turbodrill section and the rest of the BHA. The procedure includes positioning the drilling system in the hole at kick-off point, orienting the whipstock face with MWD in a desired direction, anchoring the whipstock by hydraulically setting the anchor, disengaging the BHA from the whipstock and commencing drilling operations. All of these steps take place in a single trip downhole. Once the impregnated bit and the turbine assembly pass the whipstock, the sliding and the rotating phase begins to achieve the target build rate. The authors will describe the system's components and the running procedure. They will also discuss system performance, realized benefits to the operator, lesson learned and planned improvements going forward. Copyright 2013, SPE/IADC Drilling Conference and Exhibition.
Bruton G.,Chesapeake Operating Inc. |
Crockett R.,Novatek |
Taylor M.,Novatek |
DenBoer D.,Novatek |
And 5 more authors.
Oilfield Review | Year: 2014
Polycrystalline diamond compact bits have led the way to greater drilling efficiencies in many recent plays. However, as operators push the limits of depth, temperature and distance in pursuit of new reserves, they also push the limits of drillbit life and efficiency. Recent advances in cutter technology are enhancing bit performance and durability across a wider range of lithologies than was previously possible. Copyright © 2014 Schlumberger.
Bruton G.,Chesapeake Operating Inc.
Oilfield Review | Year: 2014
Historically, drillers have relied on openhole cement plugs or cased hole whipstocks for sidetracking wells. By incorporating an innovative downhole anchor with a whipstock assembly, drillers can set whipstocks in open holes without concern for cement plug integrity. Advances in whipstock and mill design are also significantly reducing the time required to initiate cased hole sidetracks. Copyright © 2014 Schlumberger.
McDonough C.,Chesapeake Operating Inc.
JPT, Journal of Petroleum Technology | Year: 2011
American Petroleum Institute (API) threaded casing and tubing connections are expected to maintain structural integrity and sealability performance throughout the life of the well. Current industry standards specify thread dimensions and tolerances, but the critical makeup operation is specified with either torque only or standoff (position) control. One operator developed, and for the last 20 years has been using, a quality-control process for makeup that combines torque monitoring and a measurement of final assembly position. This assembly method, called "torque position," has provided gas-tight strings for critical well applications worldwide.
Kneedy J.,Chesapeake Operating Inc. |
Smith C.H.,Halliburton Co. |
Ramakrishna S.,Halliburton Co.
Proceedings - SPE Annual Technical Conference and Exhibition | Year: 2011
The Atoka Wash in Oklahoma is a segment of the arkosic detrital material that eroded from the Wichita Mountain uplift. The rock ranges in age from Precambrian to Middle Pennsylvanian. The distinguishing characteristic is the composition of carbonate matrix material. The deposition can vary from finely grained to very course, depending upon the energy of transport. Petrophysical properties of this rock contributed to confusion over the ability of the rock to produce hydrocarbon and the volume of reserves possible. Standard triple-combo logs were the logs typically run to evaluate the formation. Completions would be attempted when density/neutron crossplot porosity was in excess of 8%. Still, many completion attempts were unsuccessful, as the reservoirs would not produce at commercial rates. As one unsuccessful attempt followed another, drilling for this horizon became a discouraging and costly business. The advent of T2 bin-derived permeability from NMR measurements cast this formation in a new light. NMR logs were used to evaluate other horizons in wells, and data was acquired in certain wells where mud logs indicated shows in this Atoka Wash. The surprising result was the existence of high-permeability areas in parts of the well with very low porosity. Some wells had indicated density/neutron porosity of less than 3% but with excellent indications of permeability from the T2 bin distribution. Completion attempts were made in some of these NMR-indicated productive zones with excellent results. This paper presents the observed logs and the techniques used to ascertain these productive horizons. The usefulness of NMR bin-derived permeability to design completions is also emphasized. Finally, we will provide a comparison of the calculated productivity versus actual production for a series of these Atoka Wash wells, thereby validating the derivation and application of this NMR T2 bin-derived permeability. Copyright 2011, Society of Petroleum Engineers.
Chesapeake Operating Inc. | Date: 2014-01-27
The present invention relates generally to drill bits used in drilling subterranean boreholes. More specifically, the invention relates to drill bits and cutting elements on the drill bits and the design of each. The invention utilizes a cutting element having a convex curved top portion with a shear face wherein said shear face is a plane formed by taking a planer slice from said convex curved top portion.
Chesapeake Operating Inc. | Date: 2013-02-12
A well pad drainage system is provide, which allows for the testing of drainage water collected from the surface of the well pad prior to the release or removal of the drainage water. The drainage system utilizes a French drain in association with one or more catch basins, a drainpipe for release of uncontaminated drainage water and an extraction line for removal of contaminated drainage water.
Chesapeake Operating Inc. | Date: 2013-08-01
A system and method for drilling management is disclosed. More particularly, the present invention relates to the management of drilling data such that, among other things, drilling can be controlled to prevent the encroachment into other boreholes and into non-leased tracts of oil and gas assets. The present invention provides for a computer-based system that generates and sends electronic notices within certain well-related events which occur, such as the downloading of drilling information or when the wellbore being drilled approaches another wellbore or a non-leased tract.
Kneedy J.,Chesapeake Operating Inc. |
Atteberry J.,Chesapeake Operating Inc. |
Smith C.H.,Halliburton Co. |
Menendez E.,Halliburton Co.
Society of Petroleum Engineers - Trinidad and Tobago Energy Resources Conference 2010, SPE TT 2010 | Year: 2010
Accurate well placement and spacing, especially when using horizontal wells, is essential for optimizing reservoir development and production. In order to develop such a plan, the production mechanisms governing the reservoir must first be fully determined. Several approaches and techniques have been used to achieve this objective. The capacity of the reservoir to deliver hydrocarbons to the horizontal well bore must be understood and defined by a technique that will enable intelligent construction of a reservoir management philosophy. A variation of as little as a 30 degrees from the optimum well bore direction can result in reductions of reservoir efficiency as much as 14%. Fracture propagation achieves greater length and height when a borehole is oriented in the direction of the minimum stress. The orientation of the in-situ stress field is the critical information needed to achieve optimal placement of horizontal wells. Crossed-dipole sonic logs with directional information enable the magnitude and orientation of acoustic anisotropy to be determined, which provide representations of the in-situ stress field (Fogal 2002). After the direction of maximum horizontal stress is known, the well can be placed and the direction of the horizontal wellbore oriented to attain maximum reservoir exposure after fracture treatment. Compressional- and shear-wave slowness provided by the dipole sonic tool also enable the direct calculation of the rock mechanical properties that define fracture treatment initiation and propagation (Cipolla 1994). Because the cost of acquiring of crossed-dipole sonic data can be prohibitive, an alternative, cost-effective method for acquiring the necessary data about the in-situ stress field orientation was evaluated. Wellbore elongation is an indicator of stress anisotropy. A directional package was added to an openhole multiarm caliper and the observed borehole deformation was evaluated to determine the implied direction of the horizontal stresses. This defined regional horizontal stress information was then used to orient the horizontal component of each well. This paper compares the results derived from the examination of borehole elongation with the more precise data derived from the dipole sonic logs. This technique provides a cost-effective alternative for determining the orientation of the stress anisotropy in unconventional reservoirs. © 2010, Society of Petroleum Engineers.