workover rig cost per day made in china

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Well work and well servicing is a complicated subject and there are a lot of moving parts. It is potentially so complex that many oil and gas companies seek to avoid it altogether when they can. A thorough understanding of the rank order of the options available, and what they can do is the key to being able to unlock tremendous value. A few ‘simple’ or fortunate’ or ‘clever’ oil and gas operations can be set up where operations are simple – drill a well, complete it, produce it to abandonment pressure and conduct abandonment. For every other situation well servicing is the key to profitable operations. This is a very general way to look at the cost of well servicing, and how it affects operations in the field. The exact details will vary from country to country, field to field, region to region and company to company.

The following general group of services are available for well work. They are listed roughly in order of cheapest to most expensive for land operations.

In shallow waters with fixed platforms or other facilities with direct well access the chain of costs and values are slightly different - the overall costs are generally higher, but the general ‘ladder of values; is different also.

Pumping services tend to get more expensive offshore, because of the degree to which the equipment must be assembled on location. Wire based services still require assembly, but because the parts are smaller can usually be mobilized in larger ‘chunks’ thus requiring less assembly on location. On land, fluid pumping equipment is much more readily portable on trucks or trailers. Workover rigs on land are incredibly cheap in most places as measured on a per diem basis. Part of their advantage is that they arrive to location with most of their key components already assembled in/on one truck. This advantage disappears offshore where the rig must be assembled on site first.

In deep-water with subsea wellheads where there is no permanent facility available to access the well, costs are turned on their heads, and look roughly as follows:

Paying for a drilling rig or intervention vessel is the price of gaining physical access to the well. Everything else must be added to it to get physical access to the general area and then gain access to the well. There is no need for various forms of standalone pumping services because the vessel or rig will already have a cementing unit and/or the mud pumps available for that sort of work.

Performing the same operation over and over again has significant cost savings attached to it. Once the correct housing and supply arrangements are in place, and all the necessary people and equipment have been assembled, continuing to use it altogether ‘as is’ can save an enormous amount of money compared to dispersing it all and starting over again later. For land operations, this is most pronounced in areas where reservoir, surface, and operational practices allow for grouping wells together in relatively small areas, and for clustering well pads. Depending on what work is being done to the wells and how close together they are it may be possible to ‘hop’ from one well to the other without ever moving the equipment on a road or doing a complete rig-down.

This is one area where offshore operations can see tremendous improvements and synergies. Having facilities with multiple wells at a single physical location allows for extremely high levels of flexibility economies of scale if the same sorts of equipment and skills can be utilized on one well after another in succession.

Deepwater operations can benefit from this too, but not as much as ‘traditional’ fixed or surface access facilities, because the overall day rate of the rig or intervention vessel is often much higher, and the process of switching between wells is often much lengthier.

On land, you hire the unit and crew, and a small diem fee is added to the cost of employing them so they can stay in a hotel and get food when they are not working. The crews will transport themselves to and from the well and move the equipment to and from the well also.

Offshore, housing, food, and transportation to and from the wellsite must be arranged as part of the work to be performed. This involves contracting crewboat(s), work boat(s) helicopter flights, catering services, and crew quarters buildings with a galley, laundry, showers, toilets, etc. Extra space must be allocated or created at or near the wellsite facility for the extra quarters. Many of these same factors are also present in remote land locations. The nature of operations in the Sahara Desert, or the North slope of Alaska, or the Congo jungle are more like those offshore with respect to cost and access than they are to more ordinary land operations where ‘normal’ food and housing operations catering to the population of the area in general are accessible.

For deepwater, everything for offshore must be provided, but with the additional difficulty that none of it can be made permanent, because there are no permanent surface facilities. In addition, simply getting to the wellhead once you have a drillship, semi-submersible, light well intervention vessel or other type of access facility floating over the top of the well is a considerable challenge. Depending on the nature of the operations which must be conducted, the access method, and the weather and current conditions it may take a period ranging from a day or two, to several weeks before access to the well is accomplished and the well work itself can start.

The costs of conducting business in each of these 3 areas tend to scale very roughly in factors of 10. 100 wells making 50 bbls of oil each on land is a cash cow. Offshore that is a disaster, because the cost of servicing those wells is prohibitive. A more reasonable scenario is 10 wells making 500 bbls of oil each. In deepwater, a well making 500 bbls of oil a day is an abandonment candidate, if indeed it got that far along before abandonment. One well making 5,000 bbls a day is more. The direct cost of hiring (for example) a snubbing unit do not scale by factors of 10, but the overall cost of employing a snubbing unit do. As a result, different types of well servicing make sense in one area which may not make sense in another. On land in areas with ordinary access to infrastructure (not the Sahara or Alaska) operations like slickline are often so cheap that they are a routine procedure, with preventative or predictive maintenance schedules to scrape away paraffin or remove small amounts of scale. By contrast, it is completely cost prohibitive to try and attempt to perform similar work in deepwater – you either design and operate the well in such a way that paraffin and scale do not build up in the wellbore at appreciable rates, or you P&A the well. The cost of routine mitigation is simply too high. The relative cheapness of most workover rigs on land is another major factor. Many types of operations which could in theory be carried out in some other way are done with a workover rig simply because it is the most cost-effective technique, even if other methods might be faster, or involve fewer people. The relatively high cost of a rig for offshore facilities means that in most cases every effort short of getting a rig is tried first. Then a catalogue or list of operations to be conducted by a rig at a given facility will be gradually built up over time until they reach a critical level. At that point, a rig will be sent out to conduct all the operations which only it can perform, moving from one well another to save costs by making the work repeatable.

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OSLO, Sept 14 (Reuters) - Rental rates for offshore oil and gas rigs could rise to $500,000 in the coming months, company executives said on Wednesday.

Daily costs to hire a rig, known as the dayrate, have already more than doubled from two years ago to some $300,000, with some top-end rates reaching close to $400,000, according to Oslo-based brokerage Pareto Securities.

Drilling companies are in a stronger position to demand higher rates to rent their equipment after several lean years led to a wave of mergers and pushed them to scrap older rigs, leaving fewer available now that demand is rebounding. read more

The commodity price downturn is prompting price reductions among well service contractors in the greater Rockies outside the Williston Basin. In mid-January 2015, service providers report rates down about 10% quarter-to-quarter, similar to reports elsewhere in the oil patch as operators push the service sector for cost reduction. Meanwhile, larger service providers worry about further rate cutting from local, privately-held contractors. Rate reductions have not yet translated to reduction in wages for hands, although expectations are that pricing is going to drop further on the basis of lower commodity prices.

Among Survey Participants:Rig Demand Down QTQ [See Question 1 on Statistical Review]. Seven of the eight respondents said that demand had dropped in 1Q15 vs 4Q14 and all but one blamed lower oil prices for the slowing. One respondent that had seen a slowdown in demand said it was because they had finished all of their completion work. The respondent who had not seen an effect on demand said that their work was steady, but they were hearing of others slowing down.Mid-Tier Well Service Manager: “We are seeing demand slow for rigs and prices are being reduced. Operators are asking for 20% reductions, some are asking for 30% and they may get it. The greater reductions will be from people who are local because they don"t have the overhead expense. The service won’t be as good. On average, operators may get 15% of that 30% they are seeking in reductions.”

Number of Rigs Sufficient [See Question 2 on Statistical Review]. Six of the eight respondents said that the workover rig inventory is excessive for the current demand, while two said that it is sufficient but tipping toward excessive.Mid-Tier Operator: “Operators here are basically focusing on the higher production wells and going to ignore the lower ones. We have heard companies are laying down workover rigs. One company is going from 17 to 13.”

Well Service Work Weighted Toward Standard Workovers and Routine Maintenance [See Question 3 on Statistical Review]. Among all respondents, standard workover work accounts for 34% on average, routine maintenance accounts for 34%, plug and abandonment (P&A) accounts for 16% and completion work accounts for 16%.Mid-Tier Well Service Manager: “Our work slowed because we finished our completion work so the client gave us some production work to keep us steady till we finish this fracking job.”

Hourly Rates Consistent Among HP Series [See Question 5 on Statistical Review]. Most workover rig horsepower falls within the range of the 500 series. The 500 HP hourly rates average $310 to $400/hour depending on what ancillary equipment is contracted. See Table II for Average Hourly Rates.

Hart Energy researchers completed interviews with nine industry participants in the workover/well service segment in areas of the Rocky Mountains outside of the Bakken Shale play. Participants included one oil and gas operator and seven managers with well service companies. Interviews were conducted during January 2015.

3. Looking at your slate of well service work - on a percentage basis - how much of it is workover vs. routine maintenance vs. plug & abandonment (P&A) vs. completion work?

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.

Powerful CAT engines and a custom-made chassis that can be equipped with single wheel full suspension enable well service operations in even the most remote areas.

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.

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.

“When we look to the forecast, we aren’t really expecting a quick return to activity globally,” Ben Wilby, Senior Analyst, Onshore Energy Services at Westwood, said. “We’re expecting quite a slow, measured increase. Operators are going to remain cautious and selective with the drilling programs that they progress. That’s particularly the case for those companies who are focusing on profitability and shareholder returns as opposed to maximizing production.”

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.

On 25 August, CNPC announced plans to produce an annual average of 200,000 bbl/day of shale oil from the Gulong formation in the Daqing field in northeast China; production startup is expected by 2025. Sinopec also said it estimates a 2 billion cu m/year boost in natural gas production capacity from its Weirong shale gas field, once it begins Phase II of development next year. The field, located in the Sichuan Basin in southwestern China, currently has an annual production capacity of 1 billion cu m/year. Phase I, which involved the drilling of 56 wells from eight pads, began in late 2019 and ended in January 2021.

“Countries who have strong government mandates to increase activity are likely to see the greatest level of demand, and China is probably the key example of that,” Mr Wilby said. “There is quite a lot of upside potential in China. Should companies progress those shale developments faster than we anticipate – and it has to be said there remains relatively limited experience there, and there are concerns over infrastructure – there is the potential for activity in China to rapidly increase.”

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.

However, the country could still see a boost in gas production later this decade. Noting the high costs of offshore gas projects in Australia, Mr Wilby said the government may potentially push for more unconventional gas developments to help avoid a potential gas shortfall. These developments will likely come from smaller operators like Tamboran Resources. In June, the company announced plans to develop the Beetaloo shale basin in the Northern Territory and begin production by 2025.

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.

In Brazil, Petrobras has been farming out onshore fields as part of a divestment program, but the companies purchasing these fields are mostly smaller operators developing small-scale projects. They are unlikely to have a major impact on production over the next few years.

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.

In 2018, the Council of State, Colombia’s highest administrative court, placed a moratorium on hydraulic fracturing operations in the country. However, the court then clarified in 2019 that the ban does not apply to pilot projects.

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.

“Colombia needs to drill because they’re in a bit of trouble otherwise. They have the big problem of their reserve replacement ratio. In six or seven years, they’re going to essentially run out of supply if they don’t keep drilling exploration wells, but the majority of activity there in the last few years has been development wells because most operators are focused on getting returns from fields that are alreadyproducing. There is a potential for fracking activity, but that’s been met with quite a lot of resistance. If they can pass through that, Colombia could see quite a big bump.” DC

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As crude prices slide, oil producers are slashing new project spending. With a near 40 percent slice of a global market worth tens of billions of dollars, Chinese rig builders that offered juicy financing terms and discounts to leapfrog Asian rivals in recent years are now the most exposed to a slowdown.

Diversifying to pull out of a downturn in traditional shipbuilding, China’s state and privately owned yards have lured orders away from regional peers, building scores of rigs for downpayments of as little at 1 percent. Many haven’t yet been chartered by oil explorers, industry watchers say.

Some in the industry fear that rig builders are now heading towards a slowdown, possibly with cancellations and price cuts, that could persist longer than the oil market’s slump. Even if oil prices recover enough to stoke exploration, an inventory of ready-made rigs will be on hand, delaying new construction.

Chinese yards are scheduled to supply 37 new ‘jackup’ rigs – used in shallow-water exploration – this year, according to Nomura research, none of which has contracted customers to date. The most widely used drilling platforms, a jackup rig typically carries a price tag of around $200 million.

“We’re having a big headache because there are no orders,” said an official at a large state-backed Chinese shipyard, speaking condition of anonymity. He cited a lack of rig order enquiries for the year 2016 and beyond.

China became the world’s biggest offshore drilling rig builder after rapid expansion led by the likes of state-backed yards China Merchants Heavy Industry, Dalian Shipbuilding, a unit of China Shipbuilding Industry Corp, and Shanghai Waigaoqiao, a subsidiary of China CSSC Holdings Ltd . All three yards declined to comment for this story.

“The Chinese yards are the main culprit (of speculative rig buildup)…Even if crude oil prices are to recover as expected, we expect new-build jackup rig orders to be subdued in 2015” with considerable inventory of already made rigs available, Nomura analyst Wee Lee Chong said in a report earlier this month.

By comparison, less than 5 percent of orders at Singapore yards Keppel and Sembcorp Marine are by speculative buyers, according to Oversea-Chinese Banking Corporation. Sembcorp Marine and Keppel declined to comment.

Except for a single order won by Daewoo Shipbuilding & Marine Engineering in 2013, South Korean shipyards make very few jackup rigs, leaving the business for its Chinese and Singaporean rivals. Companies like Samsung Heavy have concentrated on deepwater drillships instead.

“Some yards might have to drop their prices by 5-10 percent in order to attract potential buyers in the current market climate,” said Lianghui Xia, a Shanghai-based shipbroker at RS Platou. (Additional reporting by SHANGHAI Newsroom and Joyce Lee in SEOUL; Editing by Kenneth Maxwell)

A new type of the 8000m drilling rig ZJ80/5850 has been researched, manufactured and successfully applied for ultra-deep well drilling in the submountain region of China"s Tarim oilfield. The new kind of rig was developed to deal with the problems of load incapacity of drilling with the 7000m rig and high cost of drilling with the 9000m rig in ultra-deep well drilling.

Deep or ultra-deep well drilling operations in the piedmont area were predominated by the 7000m rigs. In order to tackle the situation of ultra-deep well drilling in the piedmont zone in Tarim oilfield, primary technical parameters of the rig had been enhanced with maximum hook load capacity 5,850kN, 52MPa high pressure rig pumps were equipped, compacted strands high tension wirelines were first used, derrick structure of the rig was optimized, and high strength material was selected for the main structure. Thereby a perfect general technical scenario of rig and associated techniques were formed.

The Tarim basin in northwestern China featured complex geological conditions and deep buried reservoirs. The potential risk of the 7000m rig safety as drilling around 8,000m ultra-deep wells emerged and the rig accident occurred as the big-size casing was deeply set due to the bare weight of the casing exceeding the load capacity of 4,500kN. Drilling efficiency has significantly been enhanced after 22 rigs of the type 8000m rig were applied for ultra-deep well drilling in the Tarim oilfield in less than three years. The 8000m rig has become prevailing equipment for drilling operations in the submountain region of Tarim. The procurement cost of roughly USD2.5bln was cut down per set of the 8000m rig as compared to that of the 9000m rig. The daily drilling rate per rig was saved by 20%-30%. Total amount of USD36.8bln for integral cost of drilling was saved per rig per year.

The optimization of the 8000m rig parameters and advanced associated technologies have filled in the gaps of China"s rig standards and perfected the standard series of China"s rigs. R&D of the new type 8000m rig was a result of market demand and satisfied by clients for the exploration and production of ultra-deep buried reservoirs.

WILSON WELL SERVICE RIG  (Ref#3000Ta)  103’ x 248,000# derrick, Out of service since 2017, lot of rust, will start and run and/or drive down the road POR

Refurbished, 700 hp, Double drum 2042 drawwroks with Parmac 202 brake assist, (2) Caterpillar 3406 Engines, (2) rebuilt Allison 750 6 speed auto transmission with reverse. 112" x 300,000 # hook load capacity on 8 lines, clear height 97 feet, leg spread  7" 6-1/2", racking board, oil bath chain case, elevated rotary drive, all raising lines and guidelines. The Draw-works, hydro-mantic break, and crown assembly have been rebuilt. Heavy duty Draw works drive propeller shaft through right angle gear box, rotary drive propeller shaft, heavy duty reverse gear box and oil bath roller chain, and a self-locking handling winch.  Mounted on triple front axle mechanical 6 axle carrier with 134,000# capacity designed to meet highway safety standards with necessary toughness for off road operations.  Price:  $265,000

Derrick fell onto rig when being raised, derrick would need to be replaced or repaired.  Built 1981, double drum, 42 x 12, 42 x 8, swab drum removed from jack shaft, 5-axle back in carrier, 250,000# derrick with double racking board and triple rod basket, Cat 3408, CLT 5860 transmission, Cooper right angle box, 4 hydraulic leveling jacks, air rod transfer in derrick, hydraulic winch, Kerr 6 cyd 10000 psi Mustang pump powered from jack shaft, Kerr 3-valve release 10,000 psi, tong carrier f/Foster, steel work platform, Parmac 22 SR hydromatic brake.  Extra rebuilt 3408 Cat engine.  Price as is:  $112,500

Double drum, 15,000’ of new 9/16” line, near new 4-line blocks, mounted on 5 axle Crane Carrier, 104’ x 250,000# mast, 750 Allison transmission, Detroit 60 series, currently operating  Price:  $130,000

Manufactured 1981, mounted on 5 axle carrier, double triple service rig, 96’ x 250,000# derrick, Detroit Series 60 12.7 diesel engine, Allison transmission, 9/16” sandline, 1” drill line,  hydraulic jacks, hydraulic catwalk, travelling block, tubing bard, rod basket and all necessary lines.  Tooling not included.  Price:  $115,000

Manufactured 1983, double drum, 96’ x 180,000# derrick, mounted on 5 axle carrier with 92T engine, Allison transmission  Price rig only:  $300,000  Price with tooling:$340,000

WILSON 42 WELL SERVICE RIG(Ref#7562Ta)  Manufactured 1975, 180,000# Pemco double/triple derrick, mounted on Wilson carrier with Detroit 8V71 engine, 4 hydraulic leveling jacks, ready to work  Price rig only:  $74,500  Price with tooling:  $94,500

Manufactured 1983, 70" x 120,000# non telescoping stiff mast, double drum 26 x 8, Detroit 6V71 diesel engine, 740 Allison transmission with Spicer power divider, mounted on 4 axle carrier.  Rig runs and truck drives, stacked for several years, good condition  Price:  $93,500 USD

110’ x 250,000# Cooper derrick, Detroit 60 Series engine, 6061 Allison transmission, 6 axle Pettibone carrier, 3 front and 3 rear axles, drop box converted to air control, tubing drum, sand drum, 24” Wichita clutches  Price:  $315,000

FRANKS 500 WORKOVER RIG(Ref#7615Tc)  Built 1980, refurbished 2018, 102’ derrick, 150 ton blocks, 15,000’ sandline, new engine and transmission, ready to work  Price:  $430,000

FRANKS 400 WORKOVER RIG(Ref#7615Ta)  Built 1979, refurbished 2017, 102’ x 215,000# derrick, 100 ton blocks, 15,000’ sandline, 4 lines  Price:  $390,000

FRANKS 300 SERVICE RIG(Ref#1169Ta)  4-legged derrick, Series 60 Detroit engine, 6850 Allison transmission, blocks, Foster tongs, mounted on 4 axle carrier, working condition  Price:  $37,500

WILSON MOGUEL 42 WELL SERVICE RIG(Ref#3177Tb)  Two available, 96" x 280,000# mast, Detroit Series 60 engine, 5860 Allison transmission, mounted on 5 axle Wilson carrier, handling tools  Price:  $315,000

WILSON SUPER 38(Ref#3307R)  Double drum drawworks, friction clutches, Foster makeup and breakout catheads, Cummins 250 disel engine, Spicer 4 speed transmission, 70’ cantilever mast, 4-sheave crown block, racking board, mounted on 8’W x 22’L tandem axle trailer with folding walkways, mast base, 4 manual jacks, Budd wheels, National Ideal 75 ton 3-sheave block with hook, Price:  $45,000

Workover rig with 83’ telescoping derrick, 10’ crown extension, 200,000# lift capacity, 100,000# snubbing capacity.  Catwalk with 42’ reach, forward and revere motion, hydraulic pipe slide, six portable pipe racks, powered by workover rig.  5000 ft/lb hydraulic rotary, 15k psi working pressure capability kelly hose, 300 ton mast with 5 x 5 heavy wall box tubing and 2 x 2 heavy wall cross sections, (2) mast raising cylinders, 9-1/8 x 25’ telescoping cylinders/crown sheaves with cable guides, (2) winch sheaves/snubbing sheaves, SRS fall protection, retractable flow tube design, non-swivel boom pole on curb side winch, (2) mast supports, 1” lifting cables, mounted on 5 axle Crane Carrier (3rd axle drop), with 375k Volvo Penta engine, 150 gal fuel capacity, hydraulic self-leveling components, 6 speed Allison transmission, 1:1 gear box, (2) 65 gpm pumps, (2) 30 gpm pumps, (1) 28 gpm Commercial shearing pump, 40 gal accumulator storage, single man cab, hydraulic leveling jacks  Price on Request

COOPER LTO-350(Ref#3177Ta)  Manufactured 1982, 96" x 200,000# mast, Detroit Series 60 engine, Allison 5860 tranmssion, mounted on 4 axle Cooper carrier  Price:  $315,000

Manufactured 1960’s, double drum, single rig mast, 64’ x 250,000# (tubing and rod racks), 70 ton blocks, 2 lines, Detroit diesel 60 gpm @ 2000 psi, hydraulic system, air clutch.  Rig was refurbished 2013/2014 at a cost of $130,000: repairs included used 65’ derrick installed, new 1” main line, repairs to air system, hydraulic system upgrade, leveling jacks, derrick ljghting, tires, 70 ton blocks installed.  But the rig has been sitting since 2015 and now needs rebuilding. It doesn’t run.    Price as is: $19,500

Manufactured 1980, completely refurbished 2004, 5 axle double drum well service unit, double 15 Parmac brake on main drum, 96" x 180,000# hydraulic raised mast, mast lighting, Detroit 60 Sereis engine, 5860 Allison 6 speed transmission, 4 hydraulic leveling jacks, dual manual outriggers, PD12 Braden utility winch, McKissick 100 ton tubing block 21-31 diving, 1000" of 1" tubing line, 13000" of 9/16" sandline  Price:  $225,000

CARDWELL KB200B SERVICE RIG(Ref#11674Ta)  72’ x 140,000# stiff mast, 40 x 10 double drum drawworks, 2 aux deck winches, tubing board, rod board, cat walks, railing, stairs, floor BOP controls and accumulator bottles, McKissick 75 ton tubing block and hook, mounted on 5 axle carrier, Detroit 8V71 diesel engine, Alliston CLBT4460 auto transmission PRICE:  $127,500

Rig manufacture 1980, mounted on 1980 GMC Brigadier with Cat 3208 engine, includes elevators & misc tools, also includes 1996 1-ton Super Duty tool truck, tandem axle, Cat 3208 diesel, sitting 1-1/2 years  Price:  $92,500

1980, 475 hp, single drum (new), reworked, 96" x 205,000# hydraulically raised mast, 6 lines,  crown block: 3 new sheaves blocks and bearings, racking board, guide wires, (2) hydraulic hoist, weight indicator, block, elevator links, fall safety device, work platform, mounted on 4 axle carrier with Detroit Series 60 diesel engine, Allison transmission, rig in excellent condition and has been well maintained, ready for use   PRICE: $115,000

SKYTOP BREWSTER RR400(Ref#13190T) Mounted on 4 axle carrier, single drum drawworks, 8x7 disc assisted brakes, tubing board, Cat3406B engine, Allison 860DB transmission, 100 ton McKissick block, Foster 58-92R tongs, misc hand tools, approx 36" base beam for rig, ready to work  Price:  $110,000

Refurbished 2017, 4 lines, 96’ x 205,000# mast, 8V71 Detroit engine, mounted on CCC, 75 ton McKissick blocks, tubing board, rod basket, work platform, rigged up and working in field  Price:  $295,000

Manufactured 1977, 72’ x 125,000# derrick, 8V71 Detroit engine (rebuilt), Allison 750 transmission, 6500’ of new 5/8” sand line, tubing line new, drum brakes new, new style McKissick blocks, working daily  Price rig only:  $157,500

Double drum drawworks with hydromatic brake, 10" brakes, 96" x 180,000# derrick, mounted on 4-axle PEMCO carrier with hydraulic support legs, 8V71 Detroit, 4460 Allison transmission, Spicer 784 split shaft gearbox, 250 hp right angle drive, 650" of 7/8" tubing line, 8000" of 9/16" swab line, 100 ton Sowa block, hydraulic winch, hydraulic weight indicator, 84" links, 2-3/8" and 2-7/8" tubing elevators, BJ tubing slips, Foster 5893R power tongs with lift in derrick, rod hook, rod stripper, rod elevators, wrenches, transfers, rod fishing tools, misc hand tools and connections  Price:  $140,000

Manufactured 1974, double drum drawworks,  double triple 96" x 180,000# derrick with a hydromatic. The rig has working line with heavy traveling block and approx. 12,000" 9/16 sand line. Mounted on Skytop carrier with tandem steering and rear ends 4 axles W/ tag axle, 4 leveling jacks, powered by an 8V-71 with a Allison 4460 transmission, (note transmission was overhauled in early 2000"s) and the engine has a new head on right bank. The rig has two leveling jacks on the rear and two leveling jacks on the front which are located right behind the steering axels. Tooled out with hydraulic rod and hydraulic tubing tongs, air slips, rod and tubing elevators, hand tools and misc over items. PRICE REDUCED:  $115,000

Double drum, double pole 8-5/8" x 7 x65", 6,000" of 2-7/8" line, mounted on 1974 International Model 2070A tandem axle truck with Detroit diesel engine, leveling jacks, 454 Chevy propane engine on deck with 250 gallon propane tank, automatic transmission for smooth operating, Foster 58 power tongs, Guiberso air clips, tooled for tubing and rods, will do 6000" of 7" tubing, currently working    Price:  $89,500

Double drum, 70" pole, 4000" of new line, new power tongs, mud pump, power swivel, new 8.3L Cummins deck engine, mounted on 1979 Mack superliner with 400 Cummins engine, 13 sp transmission, completely tooled, 10 new bits, 4 drill collars, ready to work  Price:  $170,000

10 x 13 pole, double Drum, Franks 33” air over grease, brakes in good shape, 7/8” tubing line, tubing blocks, tong pressure adjustment, hi/low on tubing, air slips control, master kill on drawworks, Foster 36 with 8’ lift ram, air backup, swing around tong rack, mounted on 2001 Freightliner F80 truck, Cat C12 Series 3125, Fuller 9-speed transmission, PTO, winch for pole scope Tulsa 48, blocks raise pole, dual fuel tank, dual battery, 50 gal hyd tank, toolboxes, hydraulic outriggers, BJ rod tongs, ¾” and 7/8” heads, tools, swabs, extra tongs, orbits, drilling head  Price:  $242,500

Double drum (second drum is removed, rig is running as single drum), hyd pole and down riggers, mounted on 1990 Crane Carrier, 9 sp Eaton Fuller transmission, 100,000 miles, 8 x 10 telescoping poles, 3/4” cable, no tooling  Price:  $52,500

10 x 13” pole, single drum, mounted on 1980 Brigadier 9500 Series truck with 671 inline Detroit, drop box, travelling blocks, tubing lines, hyd jacks, no tooling, sitting since 2000  PRICE:  $49,500

Manufactured 1960, Double drum, all air operated, 7/8" drill line, 9/16" sandline, 60" single pole 10 x 13, mounted on Franks 3 axle carrier, will handle 8000" of 2-3/8" tubing or 6000" of 2-7/8" tubing, tools include tongs and handling tools, good condition  Price:  $69,500

Cable Tool Drilling and Completion Rig, 60" double poles rated to 150,000#, 5000" drill capacity, 10,000" pull capacity, propane Waukesha 145 engine, 500 gal propane tank, trailer moutned with International 4300 truck, last drilled 2012, 2300" drill line on drum, 3500" on spool casing drum, heavy block sandline drum, cat heads each side, tooling, spare engine  Price:  $72,500

Triple drum, casing line, sand line, drill line, 8-10” double poles, mounted on International tandem axle truck with Cummins diesel engine, 10 speed transmission, Perkins diesel engine on deck, tools, 7-7/8” carbide bit, 2 smaller bits, make up tools  Price:  $42,500 – West Texas

400’ of 7/8” block line, 9/16” sandline drum (no cable), 2000’ of ¾” drilling drum, 3 McKissick sheaves, air clutches and controls, mounted on 1961 Mack truck with 250 hp Cummins engine, older rig but runs good.  Includes elevators, oil saver pump, no BJ tongs, currently working.  Price:  $87,500 - Pennsylvania

Triple drum, friction clutch, cathead (sandline holds 2400’ of 5/8” line), mounted on tandem axle Chevy truck with 427 gasoline engine, 8-5/8” x 45’ single pole, new tires, power steering, wireline unit, good usable rig for shallow oil/gas lease, drills, workover, swab capabilities, no tools  Price:  $112,500 - Oklahoma

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Chinese yard CIMC Raffles has resumed a plan to build a ship-shaped workover rig, signalling its confidence in the offshore service market as oil prices recover.

The drillship, which was initially called Norshore Pacific, was originally designed for riserless top-hole drilling, light well intervention and well completion operations, as well as wireline and coiled tubing operations and subsea construction work in shallow and deep waters in the North Sea.

The exploration well N5 was drilled by the semi-submersible rig Nanhai VIII (also known as Nan Hai Ba Hao), operated by China Oilfield Services Limited (COSL).

After western sanctions hit Russia’s Arctic offshore petroleum businesses in 2014, the Chinese rigs have been a frequent sight in Murmansk and the Kara Sea.

“As a result of drilling and testing of an exploratory well, commercial gas inflow was obtained with a flow rate of about 600,000 cubic meters per day,” the partially state-owned gas company informs.

In 2017, it also drilled at the Leningradskoye license, while it in 2018 drilled at the nearby Rusanvoskoye license (Dinkov field). In 2019, the rig was back at Leningradskoye license, then making a finding that upgraded field resources to as much as 1,9 trillion cubic meters, as reported by The Barents Observer.