Drilling Ahead Oilfield Social Network


The Typical Treatment Solution Introduction About Drilling Waste Management

By gnsolidsamerica, 2016-05-25

Drilling Waste Management is a necessary work in the oil & gas drilling industry. In this article, we will introduce the typical treatment solution with the drilling waste from GN.

As the top leader that has been only focusing on the solids control & drilling waste management almost 10 year, GN accumulates too much experience with the DWM.

  1. Oil-based drilling waste

For the oil-based drilling waste, the recommended typical treatment solution from GN is: Vertical cuttings dryer + Decanter Centrifuge.

The 1st-stage is to use the dryer and realize the solid-phase & liquid-phase separation; Then the 2nd-stage is to use the centrifuge to make the further separation with the liquid-phase gotten from the 1st-stage. And by the centrifuge’s high speed rotation, the very fine solid particles (usually over 2-5μm) in the liquid-phase will be further separated out and get the more cleaner liquid can be gotten. The cleaner liquid will be recycled.

  1. Water-based drilling waste

As proved by practice, the vertical cuttings dryer has good effect with the oil-based waste, but the High-G shaker has a better effect with the water-based waste. So for the water-based drilling waste, the recommended typical treatment solution from GN is: High-G shaker + Decanter Centrifuge

The 1st-stage is to use the High-G shaker, the drilling waste will be further dryer and liquid-phase will be collected. Then the collected liquid-phase will go into the centrifuge and be further treated as above.

After finishing the treatment as above with the drilling waste, the final collected liquid-phase (water, oil) will be recycled and used, so how about the further dried drilling waste?

Usually they will be mixed with some other materials to finally make up the construction materials like the bricks, etc.

Finally, Welcome to contact us for any need about the equipments or system, GN can make the customized solution for you.

Posted in: default | 2 comments

GN Solids Control: How to choose the proper centrifuge?

By gnsolidscontrol, 2016-05-19

As we know, centrifuge is a widely used machine in the solid-liquid separation field, which is widely used for treating the drilling mud, drilling waste , industrial slurry separation, etc.

<span>Different applications or use have different requirements with the centrifuge. In this article, we will introduce the knowledge about how to choose the proper centrifuge.</span>


  <li><span>According to the specific use to choose</span></li>


<span>Usually the rotation speed of centrifuge is high, the high speed also means the wear of inside some parts will be fast. Such as,</span>

<span>If the centrifuge is only used for “Solids Control” (separating out the solids from the mud or slurry), choose the lower (1800~2500RPM) speed centrifuge is enough;</span>

<span>If the centrifuge is only used for “</span><a href="http://www.gnsolidscontrol.com/drilling-waste-management/"><span>Drilling Waste Management</span></a><span>” (separating out the very fine solids in the drilling waste), choose higher speed (over 3000RPM) is necessary</span>

<span>   If for both use, a </span><a href="http://www.vfds.com/blog/what-is-a-vfd-control-panel"><span>VFD </span></a><span>decanter centrifuge is recommended, its speed can be adjusted according to the actual use, but the price will also be a little high.</span>

<span>   So if the customer can identify the use, choosing corresponding </span><a href="http://www.gnsolidscontrol.com/decanting-centrifuge/"><span>decanter centrifuge</span></a><span> will be important for control the cost;</span>

<ol start="2">

  <li><span>According to the treatment capacity to choose</span></li>


<span>Usually, in the Oil &amp; Gas industry the required treatment capacity in unit time is big (200GPM or above); but in the other industry like the mining, industrial waste management, the required treatment capacity it will be small (40GPM or even small);</span>

<span>According to the actual required capacity, choosing the corresponding centrifuge will be necessary;</span><span> </span>

<ol start="3">

  <li><span><span>  </span></span><span>According to the Ex standard to choose</span></li>


<span>Different application fields have corresponding Ex regulation, such as the Exd</span><span>Ⅱ</span><span>Bt4, IEC, ATEX, etc. Choosing the centrifuge with proper Ex standard is also important for controlling the cost;</span>

<span>Finally, Welcome to contact us for any need about the </span><a href="http://www.gnsolidsamerica.com/"><span>solids control </span></a><span>equipments or </span><a href="http://www.gnsolidsamerica.com/drilling-mud-circulating-system.html"><span>mud mixing system</span></a><span>, GN can make the customized solution for you.</span>

<span>Web</span><span>:</span><a href="http://www.gnsolidsamerica.com/"><span>http://www.gnsolidsamerica.com</span></a><span> </span>

<span>Email</span><span>:</span><a href="mailto:usa@gnsolidscontrol.com"><span>usa@gnsolidscontrol.com</span></a>

Posted in: default | 0 comments


By Jason Bott, 2016-04-14

Today’s business world is one of constantly increasing complexity, with ever greater risks to personnel, property, equipment, and the environment, alongside ever-growing governmental and industry regulation. Naturally, many companies are, as a result, investing more in the field of Health, Safety, and Environment (HS&E). HSE programs are those which aim to create a work environment that is safe for employees and the public, eco-friendly, and in compliance with any laws and regulations pertinent to a company’s field of operations. Relevant considerations include occupational safety and health; accident prevention; policy and practice oversight and revision; reduced use, reuse and recycling of resources; and general environmental friendliness, among others. Among HS&E systems, there are two main categories: paper-based and electronic. This article will explain the basic features of HS&E and take a look at the significant advantages of shifting your company’s HS&E system to an electronic one.

Standard Features of an HS&E System

Some common features of an HS&E system are listed below:

  • The setting of HS&E goals and the subsequent drafting, revision, implementation and communication of policies, with the aim of keeping up with (or exceeding) corporate standards and complying with pertinent regulation. This process would involve all levels of management and staff, both as a whole and according to division.
  • The definition, documentation, and communication of roles, responsibilities, and accountabilities related to HS&E. This entails both in-house interrelationships as well liaising with external bodies, such as trade associations or regulatory bodies. A strong HS&E program will ensure that staff are supplied with the necessary information, training and resources to maintain effective HS&E practices.
  • Continual risk evaluation and management. This includes the identification and minimization of specific hazards, both acute and chronic, and the acquisition, preparation and allocation of the requisite documentation needed for HS&E compliance.
  • Setting a timetable and milestones for HS&E implementation, while simultaneously developing contingency plans. Monitoring the progress and efficacy of policies and measures implemented, and holding periodic audits and reviews with an aim to hold relevant staff accountable and determine non-compliance, at the individual, divisional or companywide level. Documenting said audits for instructive and reference purposes, and distributing them to the relevant parties. Such documentation can include incident analysis reports, citations, customer and regulator feedback forms, and risk management analysis reports.

So Why Go Electronic?

As evidenced by the above list, a robust HS&E system naturally entails a great deal of documentation of all kinds, both in terms of outside documentation used for reference and planning (e.g. governmental regulatory codes), as well as in-house documentation produced to establish, implement and review HS&E processes. Apart from the sheer volume of basic documentation, many forms and reports will also undergo endless drafts, revisions and customizations, producing a yet longer paper trail. With this in mind, going electronic with your company’s HS&E is the logical choice, as it can spare you from drowning in a sea of paperwork.

First and foremost, an electronic HS&E system instantly eliminates a massive amount of paper documentation, which as a result both cuts down on the associated costs and hassles of physical paper printing, storage and filing. At the same time, electronic documents are immensely easier to tweak, as your business and industry reality changes in real time, without starting over from scratch. For instance, stock forms (whether in-house or external) are limitlessly customizable in electronic format, to accommodate the specific needs of your company, whether in terms of management, training, audits, etc. What is more, an electronic HS&E system allows for the seamless importation and integration of external documentation, as well as the sharing of in-house documentation with outside bodies without any need to ship paperwork and the hassles this entails, such as shipping costs, security and the liability of lost documentation.

In addition, electronic HS&E systems make all files available to anyone authorized to access them, whether via desktop computer, laptop, tablet or smartphone, be it Android or Apple. The digital format also allows for the storage of images or other non-textual files alongside documentation, such as photos documenting incidents of non-compliance or training procedures. What is more, digital signatures are a cinch to collect and append to forms without the need to seek out the relevant party in person.

A final key advantage of electronic versus paper-based HS&E is the heightened security it offers. Rather than the physical lock and key of the traditional filing cabinet, your company can benefit from the security and redundancy of digital storage, under various encryption protocols, as well as real-time backups to keep track of updates and changes. Furthermore, you can audit any emendations made to documentation, in case of errors or even abuse. Finally, companies can choose to store documentation in the Cloud or in-house under their own proprietary firewalls – or both.


OFS PRO is a field service management system by Webcreek that combines electronic field ticketing, electronic HS&E, asset tracking, employee time tracking, proposal management and invoicing all in one integrated package. Contact us today to find out more about how we can help make your service enterprise more efficient and profitable.

What is a 4:1 Debooster?

By CrownOilfieldInstrumentation, 2016-01-31

What is a 4:1 Debooster?


A Crown 4:1 pressure sensor debooster is used in a hydraulic system to sense pressure and transmit this pressure to a hydraulic pressure gauge.   This sensor consists of a 4:1 debooster housing, 4:1 piston, debooster cap, check valve, hex stainless steel cross, and diaphragm separator (CD401)and 1502 union.

How Does A 4:1 Debooster Work?

As the pressure is transmitted through the hydraulic hose on the outer side of the debooster, it is 4 times stronger than after it passes through the debooster.  The deboosters housing is engineered to reduce the pressure at a ratio of 4:1 and works with a rubber diaphragm to achieve this reduction.  As the hydraulic fluid enters the debooster, it fills the chamber and the pressure is lessened.  For example, if the pressure is 16,000 PSI on the drilling side of the debooster, it will be 4,000 PSI on the gauge side of the system.  

Advantages of Using a Debooster

All Crown pressure sensors are engineered to withstand the harshest oilfield conditions.  A debooster will protect the sensitive gauge internals from harsh drilling fluids.  Because the Bourdon tube and linkage assembly are the most sensitive part of the gauge, they must be protected and a debooster does just that.  The second advantage to using a debooster is that it reduces high pressure to a lower pressure, protecting workers. High pressure hoses are subject to intense pressures, especially in fracking and cementing situations.  By reducing line pressure, workers are protected from a possible hose leak or blow out.  Third, high pressure hoses are expensive, and a debooster can lessen the cost of operations because it requires lower pressure hoses to transmit pressure to the gauge.  Fourth, hydraulic systems are easy to repair in the field, which ensures long, dependable use.  Finally, deboosters, because they are hydraulic systems, do not require electricity to operate.  When electrical components are unavailable or when an economical option is needed, a debooster is the best choice.

4:1 Deboosters are available in a variety of pressures and durable and dependable in the harshest conditions.  



Selecting a Tong Torque Gauge

By CrownOilfieldInstrumentation, 2016-01-01

Selecting a Tong Torque Gauge

What Is Torque?

Torque, measured in foot/pounds, is a force that twists an object that causes rotational motion.  When torque is applied to oilfield tubulars, that force needs to be measured in order to avoid twist offs.  Using a tong torque gauge will assist the driller in determining the max torque needed to make up and break out the drill string.

What Is a Tong Torque System?

Crown Oilfield Instrumentation offers a complete line of tong line pull and tong torque systems for use with manual and hydraulic oilfield tongs.  Tong torque systems are used with manual or electric tongs when the handle length is known and is not changed.  Unlike tong line pull systems, tong torque systems are not universal, meaning not interchangeable with a variety of tong handle lengths.  These systems measure the foot pounds of force that are applied to a  compression or tension load cell and transmit that information via a hydraulic hose to the gauge.  These gauges, either available in box or panel mount, are located on the driller's console.

How to Select the Right Tong System?

In order to select the right tong torque system, the following information is needed to be sure that you have the best system for your application. First, you'll need to know if you'll be using these gauges with a manual or electric system and if you'll be using a tension or compression load cell.  Second, you'll need to know the max capacity that will be measured.  Gauges, like car tachometers, work best at 3/4 scale or less.  Think of the red zone on the tachometer that measures the working speed of your car's motor.  Hydraulic gauges work best below three quarters of scale, just like your car's motor. So, if you know max torque then you can use a gauge within the 3/4 scale tolerance and be able to measure any extreme values above tolerance.   Next, the handle length is needed to calibrate the gauge and select the proper load cell.  The whole system is calibrated based on the max torque and the handle length of the tong in our factory so that the driller does not have to do so.  All of these parts of the system, gauge, load cell, and hose, work together to show the driller what foot/pounds of torque are being applied to the oilfield tubulars that he his working with.

Tong Torque Gauges

Tong Torque gauges are built to last and stand up to the harshest industry conditions.  Because these gauges are fluid-filled, they resist fluctuations and vibrations that result in day to day rig operations.  With a target pointer attached to the gauge glass, the driller can easily see at a glance when max torque is being achieved.  These gauges, along with the complete system, are easy to repair in the field, offering a lifetime of dependable use in the field.

RWD in the Miss Lime

By cole.mick, 2015-08-05

Our Mississippian Lime wells have been costly to drill sometimes taking up to 70 days. We have to make short trips and extra reamer runs to smooth the hole. Not many companies ream while drilling in the Miss Lime but I think it may save some some time and money. What are your thoughts? thanks

Not reporting accidents

By Not Happy, 2015-07-27
Anyone else find it troubling that a company as big as Nabors can't afford to file an accident report or pay an injured worker... Yet they have the man power to alter records and lie and hide things...trying to locate workers from rig 245 that were working on the North Slope and are aware of a fall that occurred and was NOT reported. If anyone knows anything... Please let me know.

A first for Thailand: Buying property with a 20-year visa

By kingdomproperty, 2015-07-13

A first for Thailand: Buying property with a 20-year visa

In what is the first initiative of its kind in Thailand, one property developer has joined forces with Thailand Elite to offer a 20-year visa for purchases at its Pattaya condominium.

Purchasers at Kingdom Property’s Pattaya Southpoint development will be entitled to a 20-year visa, which amounts to five-year multiple-entry visa that is renewable every four years.

The visa will entitle its holders to benefits that include fast-track immigration clearance, assistance with driving licences, discounts and a bilingual helpline.

Nigel Cornick, Chief Executive Officer of Kingdom Property (pictured), said: “The long-stay solution will overcome many of the barriers that we see when selling our properties overseas. Generally unless you have a business visa, retirement visa or marriage visa, you are not permitted to stay for any length of time.

“This exciting partnership is akin to Malaysia’s My Second Home (MM2H) program and has massive potential.”

The visa will come as part of the purchase of a unit at Southpoint and the owner can sell the unit and the visa together, if he or she so wishes.

“The target demographic for this initiative is very wide,” added Cornick.

Website Link: http://www.kingdomproperty.com/20-year-visa/


Youtube Link:  https://youtu.be/98-bCbLguj0 

Posted in: default | 0 comments

Baker® Style Drill Pipe Float Valves | Keystone Energy Tools LLC

By bizzuka1, 2015-05-26
All KET Float Valves are manufactured with alloy steel integral, cages & plungers to produce the most reliable float valve on the market today.
Posted in: drilling | 0 comments

5th Anniversary of the Macondo Blowout

By George Baker, 2015-04-18


What’s Been Missing from the Macondo Explanations?



On April 20, 2010, the loss of control of the Macondo well led to the loss of Deepwater Horizon (DWH) and the lives of eleven contractors and crew members. The resulting oil spill would cause the greatest ecological damage in the Gulf of Mexico since the blowout of Pemex’s well Ixtoc-1 in 1979.


In a series of technical papers, Ron Sweatman and several industry colleagues, among them Juan García, formerly director of global drilling at Exxon, and Robert Mitchell, former Halliburton Technology Fellow, came to a new understanding of the root cause of the Macondo accident—that is, the original reason why formation fluids entered the wellbore several hours after the cementing operation.


This new understanding uncovered a technology gap in drilling and completion operations.  Neither in 2010 nor at present, has there been a downhole tool or software program that could have alerted the mud crew that disaster was ahead. In 2015, with similar well conditions, both drilling and completion crews are as much at risk for the loss of well control as they were in 2010 in relation to the root cause of the Macondo accident.


Long before 2010, it was known as a general fact of fluid mechanics that all fluids to some extent are compressible and can shrink or expand; that is, changes in pressure or temperature will result in changes in density.[1]  It was known that a drilling fluid called synthetic-based mud (SBM) is highly compressible with a much higher coefficient of thermal expansion compared to water-based mud.


The oil industry had been aware that during drilling operations with SBM (which was used as the drilling fluid on the Macondo well) shrinkage could occur; but there was no way to differentiate actual shrinkage from the static loss of circulation, or “top-level fallback,” that occurs when fluids have leaked into the formation that surrounds a well. In either case, the correct response would be to insert mud into the wellbore. If the mud crew fails to make this response during drilling or cementing operations, the risk of a blowout is created, as shrinkage brings with it a loss of hydrostatic pressure.  During cementing, a loss of density compromises the integrity of the cement during the curing phase of 14-21 hours.


In 2010, the science that explains the need for an open fluid column during the curing phase was only partially understood. Missing then was a precise understanding of the effect that changes in wellbore temperature have on volume, hydrostatic pressure and density. In API’s standards today, an explanation of the need to maintain an open fluid column during curing is only minimally presented; readers are left with the mistaken impression that hydrostatic pressure would be unaffected by isolating the wellbore from the riser.


On Macondo, the installation of the casing seal at the wellhead shortly after the placement of the cement created a closed system, which meant that the hydrostatic pressure would now respond to changing conditions in the wellbore. These changes would be undetectable by the crew.


The higher temperature of the rock formation affected the properties of the fluid: As the SBM in the casing cooled, a thermal-induced shrinkage led to a loss of density which, in turn, led to a loss of overbalance pressure in the trapped fluid column (from the wellhead to the hydrocarbon-bearing formations).


When, during the first two hours in which the cement was still a slurry, the equivalent density, or hydrostatic pressure, became less than the pore pressures in the rock formations, creating an underbalanced condition. Formation fluids, brine, oil and gas, penetrated the wet cement, creating flow channels into the weak zone below.


Over time, the flow channels grew larger, eventually building up sufficient pressure to penetrate the shoe track and enter the casing from below.


During this process, the DWH crew received no data or warning that the cement would not serve as a barrier. Today, there still is no commercial software product that would enable the thermal modeling of the behavior of drilling fluid in cases like this where geothermal gradients could affect fluid temperatures and pressures; nevertheless, there are measures that may be taken to cancel the effect of temperature.  For example, the fluid’s temperature vs. the geothermal gradient may be made more stable by a complete top-to-bottom conditioning of the mud, a precaution not taken on the DWH.  In some cases, mud temperatures may be adjusted on the rig to lessen the downhole effects. In addition, the setting of the casing seal should be delayed until after the cement sets hard enough to create a pressure barrier.


Looking back, neither drillers nor operators understood the importance of knowing about the changes that the formation can induce into the drilling fluid. They did not appreciate the danger that such changes could lead to an underbalancing of the well. It was this undetected change that occurred at the Macondo well that, combined with subsequent mechanical and human failures, led to the blowout and loss of the rig.


Looking forward, commercial software is needed to allow for routine thermal modeling in which the undetectable changes in the fluid properties are calculated as the fluid temperature equalizes with the surrounding formation temperature.


With the aid of such software, profiles over time may be plotted that show the effect for formation-induced changes on the properties of the drilling fluid.  Such profiles would tell you if such changes induce the heating or cooling of the fluid. At Macondo, it was the cooling effect that led to the compromise of the integrity of the cement barrier.


In the meantime, the curricula of training schools, plus API standards, need to be updated to include instruction and guidance from this poorly understood risk to drilling and cementing operations.





Posted in: News | 0 comments