workover rig inspection checklist made in china

Rig Check was developed by the National Institute for Occupational Safety and Health (NIOSH) in partnership with safety experts from the oil and gas extraction industry. It is made up of 35 inspection forms. The forms are designed to be used by rig workers to document the inspection of tools and equipment commonly found on rotary and workover rigs. Each inspection form includes instructions for assessing and recording the condition of the equipment. When applicable, relevant federal regulations and industry recommended practices are included.

The Rig Check inspection forms are an excellent training tool for short service employees, who may not be familiar with the tools and equipment found on oil and gas rigs. Small companies whose safety and health resources are limited may find Rig Check useful for enhancing their HSE programs.

Ensure that each well has an emergency response plan, which includes simple instructions for notifications in the event of a rig-based emergency. Notification protocols for medical emergencies, fire on the rig or location, gas release or loss of well control, or a security breach should all be included. In most cases, there will be contingency plans in place for the well that address notifications for long-term events that include notification of government agencies and outside well control expertise. These contingencies can be noted in the working plan but should not complicate the posted action plan.

LOCATIONS: Write locations of posted, current emergency response plans. These should be in central locations such as the rig doghouse, change house, Rig Supervisor’s office, Company Man’s office, and rig camp.

In addition, check that the response plan is posted anywhere emergency communications may be made, including the Rig Supervisor’s truck, and the guard shack.

ALARMS:Rig emergency alarms may be automatic or operated by personnel from various locations manually. Whichever the case, the alarms should be heard throughout the rig and on the location. The alarms should be distinctive and easy to identify as to their purpose. Alarms that work in conjunction with lights should be visible from the entrance of the location. It is a good practice to include a wind direction indicator in close proximity to the lights. All employees should be trained to activate manual alarms and understand what triggers automatic alarms.

DEVICES:Emergency shut-down devices (ESD) that will close off the combustion air should be installed on all of the rig’s diesel engines. It is important to understand just how particular ESD functions BEFORE you attempt to test it. Engine shutdowns or rig savers may damage engine components if they are engaged when the engine is running at speed. Careful plans should be made with the mechanics to develop a test protocol that will ensure the functionality of the devices without damaging the engine. In most cases, these devices can be checked with the engine shut down. Manual engine shutdown devices that shut off the fuel to the engines can also be tested while the engine is shut down.

SMOKE ALARMS:Smoke alarms in trailers and outbuildings should be function tested monthly or following a rig move. Note on the inspection form when batteries are changed each year.

the rig should have a written plan for calibrating and testing alarms and shutdown devices. The inspection should include a review of these documents to ensure new equipment and or rig modifications have not altered the function of the devices.

These checklists are not all inclusive. You may wish to add to them or delete portions that do not apply to your workplace. Carefully consider each item as you come to it and then make your decision. Do not spend time with items that have no application to your workplace.

This website is using a security service to protect itself from online attacks. The action you just performed triggered the security solution. There are several actions that could trigger this block including submitting a certain word or phrase, a SQL command or malformed data.

Download Workover & Drilling Rig Inspection Checklist As we mentioned in the Rig Audit Article, rig inspection is an important process that shall be done from time to time. Especially, after the rig moving to a new drilling location.

Rig Inspections will be conducted using the OCS Group Acceptance Guidelines Program, which includes testing of all equipment and systems to verify their condition and performance.

Intrusive inspections of the internal parts of specific equipment including critical measurements and clearance to ensure equipment is running within recommended tolerances.

Verification that the rig equipment complies with API standards, the equipment manufacturer’s specifications and recommendations and good engineering practices.

Rig Inspections are preferably completed between wells, so access to all equipment can be managed however they can be completed at  Inspections can also be conducted when the rig is at the well location so full testing can be safely and efficiently conducted.

The assistance of the crew is required to operate the equipment for testing, and assist with testing of various items such as isolation or preparation for internal inspection, including measurement of clearances. During the inspection the rig has to be adequately manned, and the crew must be familiar with the rig specific systems.

All consumables and equipment should be available on the rig like water in the pits, a sufficient quantity of barite and sufficient drill pipe to make up stands.

Oil and gas is an extensive industry with a lot of work in the field. Mobile business apps contribute to the convenient and efficient oil and gas field work. With a constant access to a real-time data management or any inspection can be conducted instantly just by using a mobile device. Oil and gas field work needs speed with maintaining the quality. Mobile apps could easily afford it.

Snappii, a rapid mobile app development company, offers a set of mobile business apps which can be a great helper in any oil and gas field work. Oil and Gas Rig Inspection mobile app is designed for inspectors and maintenance personnel engaged in oil and gas field work and consists of digital forms covering the most important aspects of the rig inspections like:

With Oil and Gas Rig Inspection mobile app oil and gas field work becomes more regularized and accurate. You can work in online and offline modes and always stay connected. Moreover, mobile forms eliminate paperwork and allow users to work with documentation remotely. All inspection paper forms often get lost, it’s difficult to read handwriting and mistakes and inaccuracies are often made. With mobile data collection in mobile forms format you can forget about these challenges.

Their exceptional mobility, stability, and ease of operation are the outcome of our extensive experience in the design and production of mobile drilling rigs.

Belonging to the same family, Sovonex™ service rigs comprise many of the technological advantages that result in smooth operation and make the life of our customers’ easier:

Wide selection: At our production facility in China we design and develop workover rigs for service depths ranging from 1,600 m to 8,500 m (5,250 ft-27,900 ft), and workover depths from 2,000 m to 9,000 m (6,600 ft-30,000 ft) for 2 7/8” DP.

Full API coverage: The different components of our well-servicing rigs are manufactured to the following API standards:Steel structures, such as the mast: API Spec 4F

Highly maneuverable : Sovonex™ mobile drilling rigs and self-propelled workover rigs possess excellent driving properties in the desert, mountain, and other impassable terrains.

Reduced NPT: The mast is erected hydraulically to reduce time for rig up and increase safety. Likewise, all rig components have been designed to allow for fast assembly and disassembly.

With every service rig, we send technical staff to our customer to provide first-hand technical support. The engineer responsible for the rig design is always part of the service crew.

SCOPE: To provide a representative basis for determining the availability, capability, dependability, reliability of Stability Systems on Land Based Work-Over Rigs and the recommended practices and procedures for their safe use.

The rig location area may grade away from the well bore along centerline II at a maximum drop of 1:20. The cross grades, parallel to centerline I, should be level. The area shall provide a minimum bearing capacity of 6000 psf.

Using the chart: An anchor in Zone "A" located a horizontal distance of 70 feet from the "Well Head" would require an anchor of what minimum holding capacity? On the chart move along the horizontal legend from left to right until you reach 70 feet. At this juncture proceed vertical until you intersect the curved line for Zone "A", now follow the intersecting horizontal line, left toward the vertical legend. We have now determined that the minimum holding capacity for the anchor, at this precise location, is 20,000 pounds.

Standing at the "Well Head", with the well bore immediately to your back, proceed North (in direction monkey board is facing) 24 paces. (The pace length is not as important as the numerical relationship of the units and the consistency of the unit length. The method will work with any unit of length as long as the same unit is used throughout.) Place a stake or other marker at this location (Bench Reference). Turn West 90 degrees and proceed forward 10 paces. At this location turn your body so that the front portion of your anatomy is approximately parallel to the radial of the guy anchor. If the northwest guy anchor is forward of your right shoulder and the southeast guy anchor is aft to the rear of your left shoulder, it can then be presumed that the radial angles are within acceptable parameters. Repeat the procedure from the bench reference, this time to the east, proceed ten paces. In this orientation the northeast anchor should be forward of the left shoulder and the southwest anchor should be aft of the right shoulder.

A survey of 13 drilling contractors operation 193 drilling rigs in northern Canada and Alaska indicated that there is a wide range of experience and operating practices under extremely low temperature conditions. While there is very little precise information available, there have been a sizeable number of failures in portable masts while in the lowering or raising process in winter. Thus the exposure to low temperature failures focuses on mast lowering and raising operations. Based on reports, however, this operation has been accomplished successfully in temperatures as low as -50 degrees F. While the risk may be considerably greater because of the change in physical characteristics of steel at low temperatures, operators may carry on "normal" operations even at extremely low temperatures. This may be accomplished by a program of closely controlled inspection procedures and careful handling and operation. This should reduce damage and impact loading during raising and lowering operations. At the present, there seems to be no widely accepted or soundly supported basis for establishing a critical temperature for limiting the use of these oilfield structures. Experience in the operation of trucks and other heavy equipment exposed to impact forces indicates that -40 degrees F may be the threshold of the temperature range at which the risk of structural failure may increase rapidly. Precautionary measures should be more rigidly practiced at this point. The following recommended practices are included for reference:

If maintained to these tolerances the sags will indicate a pretension of 1000 pounds for crown to ground guywires and 500 pounds for tubing board guywires. this is based on the use of 5/8 inch, 6x19, or 6x37 class, regular lay, ips, IWRC wire rope, installed according to the rigging guidelines set forth in chart depicted in Figure 5-5

The drawing on the following page, Figure 5-4, (SAME AS FIGURE 4-4) is another illustration of the continuing evolution of Rig Stability System engineering and design. It represents the latest API thinking relative to planing and preparing a Rig Stability System.

CAUTION: SOLE EMPHASIS SHOULD NOT BE PLACED ON PULL TESTING OR ALTERNATIVES TO PULL TESTING AS THIS MEASURES ONLY ONE COMPONENT OF THE RIG STABILITY SYSTEM.

The rig contractor should be responsible for the following: a. Insuring that anchor capacities are verified and that anchor spacing and capacity is suitable for the mast guying pattern and anticipated loading.

b. Records of pull testing or records of other methods used to verify temporary anchor capacity should be retained by the rig contractor until the job is complete and the guy wires have been removed from the anchors. The records should indicate the capacity of each anchor, the date of verification, name and phone number of the party responsible for verification, and the soil condition at the time of verification.

Temporary Anchors, installed in accordance with the manufacturer"s specifications, may be deemed to be representatively pull tested, if upon inspection the following is observed:

OUT OF AN ABUNDANCE OF CAUTION IT IS EXTREMELY IMPORTANT TO POINT OUT THAT THE PREVENTION OF RIG UPSET IS DIRECTLY DEPENDENT ON THE TOTAL INTEGRITY OF THE RIG STABILIZATION SYSTEM. THE SYSTEM INCLUDES ALL OF ITS COMPONENTS AND IS ONLY AS SOUND AS ITS WEAKEST MEMBER.

Our research has concluded, that the latest State-of-the-Art in RIG STABILIZATION is to be found in the pending American Petroleum Institute, Recommended Practice for MAINTENANCE and USE of DRILLING and WELL SERVICING STRUCTURES.

Kelly bushings on oil drilling rigs that are smooth and do not present a potential hazard to employees that might come in contact with the bushings, do not require guarding.

The automatic operation equipment for minor workover is mainly composed of a wellhead operation device, hydraulic elevator, pipe and rod transmission and arrangement device and electro-hydraulic control system.

The device adopts the structural form of dispersing the functional modules and integrated installation on the workover rig: with the hydraulic tong, manipulator and anti splash snap device set on the derrick of the workover rig, which can expand and rotate, and the safety slip is installed above the BOP.

The device only needs to install safety slips, which realizes rapid installation and migration and shortens the auxiliary working time. The device has the function of moving back and forth, left and right, which is convenient to align the wellhead. The height of the hydraulic tong is adjustable and can adapt to the wellhead with different heights. Hoisting equipment and special transport vehicles are not required for the installation and removal of the device.

The main electric control box can be installed on the operation vehicle or integrated into the modular wellhead operation device. The make-up torque of various oil pipes is set on the touch screen to realize automatic make-up and break-down. Equipped with video monitoring, process prompt, safety alarm, etc. The control system has a perfect action interlocking function to ensure the safety and reliability of the workover operation process. All of the electric cabinets, sensors, connectors meet the requirement of Explosion-proof on field.

This website is using a security service to protect itself from online attacks. The action you just performed triggered the security solution. There are several actions that could trigger this block including submitting a certain word or phrase, a SQL command or malformed data.

ZPEC 2000HP Workover Rig VFD possess excellent driving properties in desert, mountain and other impassable terrains. Their exceptional mobility, stability, and ease of operation are the outcome of our extensive experience in the design and production of mobile drilling rigs. ZPEC 2000HP Workover Rig VFD is real workhorses, perfectly adapted to operate in even the roughest environments.

ZPEC 2000HP Workover Rig VFD is used in the heaviest application, such as complete well work-over operations, whereby a well is killed (production stopped) and tubing and completion equipment is removed. A Workover Rig is similar to a hoist or a telescoping tower secured with wires, that allows pipe and down-hole equipment to be run into and out of a well.

VFD rigs help advanced drilling technologies such as pad drilling, horizontal drilling and directional drilling. ZPEC VFD rigs come with high level of automation that involves automated drilling pipe handling, drill pipe connection and auto drilling.

Near-term outlook characterized by cautious optimism, with China, Russia and Middle East expected to drive bulk of growth in rig and well counts out to 2025

The past two years have been tough for the international onshore land drilling market, from Asia Pacific to Europe to the Middle East to Latin America. Going into 2022 and looking out to 2025, however, things are looking up, according to Westwood Global Energy Group’s 2021 World Land Drilling Market Forecast. The firm is forecasting increases in most relevant metrics, including rig count, utilization rate and number of wells drilled.

By 2025, Westwood expects operators will be drilling an estimated 50,200 onshore wells globally, up from just 38,500 in 2020 and approaching the 52,000 wells drilled in 2019. This is expected to drive global land rig demand up to 4,560 rigs by 2025. That’s a nearly 30% increase compared with a demand of 3,530 rigs in 2021 and nearly matching the 4,570-rig demand level seen in 2019.

At the same time, total rig supply is expected to remain flat, at around 9,000, through 2025. This sets the scene for improvements in utilization rates, which is forecast to improve from 39% in 2020 to 50% in 2025.

Looking at specific markets, the Asia Pacific and Eastern Europe/Former Soviet Union (FSU) regions are expected to be the primary drivers in demand growth for land rigs over the next four years. Westwood projects an estimated annual average of 1,430 operational rigs, defined as rigs either drilling or in the process of mobilizing to a field, in Asia Pacific from 2021-2025. This is more than any other region in the group’s analysis. Eastern Europe/FSU is estimated to average 1,130 rigs over the same time period, followed by North America at 890, the Middle East and North Africa (MENA) region at 560, Latin America at 170, Sub-Saharan Africa at 30 and Western Europe at 10.

In terms of the broader oil and gas markets, supply and demand is expected to remain tightly balanced over the remainder of 2021 and into 2022, according to Westwood. However, the uncertainty of pandemic-induced demand shocks will likely continue to loom large for years to come, keeping a ceiling on any upside in commodity prices and leading E&P companies to maintain their focus on capital discipline. While Brent had risen above $78/bbl as of 30 September, Westwood’s rig demand forecast is underpinned by an assumption of $60/bbl in its base case scenario for 2022-2025.

Not only is the Asia Pacific region forecasted to have the highest land rig demand from 2022-2025, but it will also have the highest rig utilization rate, at around 66%. China will make up the bulk of rig activity in this region. Westwood estimates the current number of operational land rigs in China at around 1,100, with a total rig supply of 1,500. Those figures should rise to 1,300 rigs operating out of a 1,600-rig fleet by 2025. NOCs China National Petroleum Company(CNPC) and Sinopec currently account for 95% of the identified rigs within the country, and that number is not expected to change significantly through 2025.

However, there could be rapid changes in the makeup of the Chinese land rig fleet in the coming years, as the country ramps up development of its unconventional resources. Currently, China has a smaller share of high-horsepower rigs compared with other regions measured in Westwood’s report. Of the 1,500 rigs there now, only 51% are high-horsepower (greater than 1,499 hp), while 36% are medium horsepower (1,000-1,499 hp) and 13% are low horsepower (less than 1,000 hp). As a comparison, 87% of operational rigs in MENA and 79% in North America are high-horsepower rigs.

Land rig utilization in China is expected to reach 80% by 2025, well above the global average of 50%, Mr Wilby said. The increase will be driven primarily by government mandates to increase domestic production, particularly in its unconventional sector. China’s latest Five Year Plan, released in February, specifically cited unconventional E&P as part of its efforts to reduce reliance on oil imports. In March, the country’s Ministry of Finance and the State Administration of Taxation also extended its 30% tax deduction for shale gas producers through 2023.

Outside of China, India and Australia are other areas of note in the Asia Pacific region. India is expected to go from 85 rigs operating and 45% utilization in 2021 to 110 rigs and 60% utilization in 2025. The number of wells drilled is forecast to average 500-600 per year over that same time frame. Westwood said it is optimistic about the growth potential in India primarily because the country has set “ambitious” production targets. In 2019, ONGC announced a goal of doubling its production by 2040. This will likely lead the NOC to be more aggressive in farming out marginal fields to other companies to help build production.

For Australia, which is still dealing with stringent travel restrictions related to the COVID-19 pandemic, Westwood’s outlook is more conservative. The forecast calls for rig count to go up from 25 in 2021 to 30 in 2025 and for wells drilled to go up from 540 in 610 in the same time span. Rig utilization rate will average 24% over the next four years. Those numbers are roughly similar to the country’s averages from 2016-2020.

In Eastern Europe/FSU, drilling activity will continue to be dominated by Russia. To meet export commitments, the country will need to sustain high levels of drilling on its mature fields. From 2021-2025, Russia is expected to average 1,000 rigs in operation and to drill 6,400 wells annually, making up around 88% of the region’s total expected rig count of 1,130 and 7,300 well count total. Rig utilization in the country is expected to average 70%. As in China, much of Russia’s drilling activity is expected to come from its NOCs.

Aside from Russia, Westwood also pointed to Kazakhstan as a country of note. While activity is on a much smaller scale than in Russia, rig demand in Kazakhstan is expected to double from 25 rigs in 2021 to 50 rigs in 2025. This growth is due, in large part, to Chevron’s planned expansion of the Tengiz field in the northwestern part of the country. The $45 billion expansion, which Chevron is set to finish in 2024, will boost the field’s oil production by 260,000 bbl/day and gas production capacity by 960 million cu ft/day.

Western Europe will be much less of a factor in the global land drilling mix. Westwood estimates the region to average just 10 rigs a year and 76 wells drilled from 2021 to 2025, with rig utilization at approximately 10%.

In the MENA region, the Gulf Cooperation Council (GCC) states are expected to drive the bulk of land drilling activity in the coming years. Rig demand here is forecasted to increase from 300 in 2021 to 380 in 2025, with utilization increasing from 55% to 70% in the same time period. Total wells drilled is expected to increase from 2,000 this year to around 2,500 by 2025.

Of the six countries in the GCC, Mr Wilby said, it will be Kuwait, Oman and Saudi Arabia that have the most potential for “significant” increases in onshore rig demand. This presumes that OPEC+ follows through on its plan, announced this summer, to end production cuts by September 2022. The cuts were enacted in 2020 following the oil price downturn.

In Saudi Arabia specifically, Westwood expects to see a significant boost in activity. The country is forecast to see a demand for 150 land rigs by 2025, a 36% increase over 2021 levels. However, the bulk of that increase will likely not come until after 2022, according to Westwood. This is partly due to the timing of the OPEC+ cuts ending, but Mr Wilby also noted the projected 2024 startup of production at Jafurah, the largest natural gas field in the country, with an estimated 200 trillion cu ft of reserves.

For Kuwait, Westwood is forecasting an increase in rig utilization, from 55% in 2021 to 70% by 2025. Wells drilled are expected to reach 600 by that year, which would be the country’s highest activity level since 2017. These figures presume the startup of Phases 4 and 5 of the Jurassic Gas project in northern Kuwait, which could add 300 million cu ft/day of gas production. A projected startup date has not been announced, but Westwood anticipates the facilities starting up in the mid-2020s. Phases 4 and 5 involve the construction of production facilities for handling and treating gas – when they are brought on stream, they will require additional rigs and wells to produce feedstock from the field.

Over in Oman, where mature fields require sustained drilling activity to maintain production levels, rig utilization has already rebounded to 70% this year, after falling from 80% in 2019 to 65% in 2020. By 2025, that number is expected to rise to 80% again, with 85 rigs in operation.

The Latin America region is not expected to see significant increases in its land drilling activity over the next four years. Westwood forecast an average of 170 operational rigs per year through 2025, while wells drilled will increase from 1,600 in 2021 to 2,350 in 2025. Rig utilization is expected to increase from 20% to 30% in the same time period.

Mexico is forecast to see modest increases over the forecast period, moving from 25 rigs, 140 wells drilled and 20% utilization in 2021 to 30 rigs, 170 wells drilled and 25% utilization in 2025. The country has laid out ambitious plans, announcing in 2019 a 25-year, $10 billion commitment to develop onshore and offshore exploration resources. However, PEMEX was mired in $115 billion in debt as of Q2 2021, which Mr Wilby said would make significant investments difficult in the near term.

Westwood’s forecast was much more optimistic when it came to Argentina, which is expected to see the number of wells drilled nearly double, from around 500 in 2021 to nearly 1,000 wells in 2025. Rig count would also increase in the same time span, from 50 to 80, as would rig utilization, from 30% to 50%, thanks to increased activity from YPF in the Vaca Muerta shale.

Colombia may also see a spike in activity. Westwood has forecast rig count in the country to increase from 25 in 2021 to 40 in 2025, utilization to increase from 15% to 25% and wells drilled to increase from 440 to 720. There is significant upside potential to this, as well, should any unconventional developments progress.

Armando Zamora, President of the ANH, said in March this year that he expects a reversal of the fracking ban in 2022 when the country modifies its environmental regulations. This could obviously lead to a boost in unconventional drilling, although Mr Wilby said drilling contractors most likely would not feel any upside until later in the 2020s. Westwood forecasts the country will have 700 wells drilled in 2025, which is similar to 2019 levels. Rig utilization, which was below 10% in 2020, should rise to 20% in 2025.

This website is using a security service to protect itself from online attacks. The action you just performed triggered the security solution. There are several actions that could trigger this block including submitting a certain word or phrase, a SQL command or malformed data.