Understand how the Completions Standardization Technical Committee (COMSTEC), comprised of members from Petronas MPM and regional operators and service companies are tackling three main operational inefficiencies: Packers, safety and flow valves and operational procedure.
In this article, we review the situation and prospects for the offshore well intervention market, with comment on best practice, based on a presentation at OWI APAC 2018 (Kuala Lumpur) by Dan Cole, McKinsey & Company.
SIA Cyclit Konsultants:
Pilipishin B., PhD,
Havenson I., PhD, Gonca V., PhD, Brushtunov V., PhD, Huk I.
Our original method of prediction hydrocarbon traps is based on the theory of sedimentary cyclicity (lithmology) and on the assumption of discompaction and compaction zones: oil or gas field is formed by hydrocarbon migration from the source of their generation and the subsequent accumulation and conservation in the traps, which are located along the ways of migration.
The method can significantly improve the efficiency of geological exploration work in all their phases and stages. One of the main feature of our method is that we definitely prove where wells SHOULD NOT BE PROJECTED. It will RADICALLY REDUCE fields’ research and exploration costs.
For last 20 years we analyzed more than 50 deposits (mainly Ukraine and Khazahstan) with really positive results: overall average probability of successful wells is more than 70%.
The “Seismocyclit” group carries out processing of customer’s geophysical data and search for oil and gas pools, using its own exclusive methodology. The proposed methodology includes original methods of processing and interpretation of geophysical data, realized in form of programme-methodical complexes (PMC) “Seismocyclit” and “AFCM” (amplitude-frequency characteristic of medium).
It allows:
– To carry out construction of stacks with improved signal-to-noise ratio, eliminating regular and irregular unwanted signals, which do not respond to the principle of reciprocity in seismic survey.
– To accomplish stratigraphic identification of the reflecting horizons, using logs in form of cyclites.
– To discover structural features of the geological section, and ways of migration – hydrocarbon delivery channels, which often coincide with tectonic failures.
– To single out zones, where reservoirs and impermeable beds are developed. For these goals, the sections of “AFCM” (amplitude-frequency characteristic of medium) are used, which are characterized by important and distinctive feature: the calculation of colour instead of it’s assignment. Changing of the colour on the “AFCM” sections shows that the reservoir characteristics of the section change. In the given variant of calculation, horizons of the reservoirs are displayed on the “AFCM” sections in dark blue and black colour. The efficiency of this methodology is proven on a number of structures and fields connected to various types of sections. On the presented “AFCM” sections, four boreholes (red colour) are shown, which were drilled with the help of our recommendations and have given the production in terrigenous section.
These programme-methodical complexes (PMC) “Seismocyclit” and “AFCM” – amplitude-frequency characteristic of medium have been effectively used for prognosing traps in Upper Jurassic carbonate section of Precarpathian deep.
On the “AFCM” section in the upraised block of Upper Jurassic deposits, the extensive zone of reservoirs development can be pointed out, whose presence is proven by the results of boreholes testing. In the upraised part of the sinked block we can point out similar zone which is prospective.
– Additionally for prognosing the presence of hydrocarbons in trap the data of electrical prospecting can be used – it may help to calculate longitudinal electrical resistance on several deep levels. The existence of structural form and higher resistance on certain stratigraphic levels can indicate hydrocarbons’ presence in the structure.
The proposed methodology of hydrocarbon pools forecasting can be used at any stage of geological prospecting works, significantly raising their efficiency.
The following input data are necessary for our job:
As the result of the works the Customer will obtain the following main materials:
Fahmi Ghaffar, Well Services Manager of PETROFAC shares the past three years of their well intervention experience to show the efficiencies and lessons learnt that have been noted during this period.
Agha Nadeem Durrani, Deputy Chief Engineer – Well Interventions from Pakistan Petroleum Limited shares a case study from a recent parted tubing campaign.
By Mark Plummer MSc BEng
In March, 2017 ISO released their Latest Well Integrity Standard, ISO 16530-1: Life Cycle Governance. In this article I will provide the background to the standard and discuss some of the key sections contained within.
BACKGROUND TO ISO 16530-1
KEY SECTIONS OF ISO 16530-1
All well life cycle phases have common elements, methods and processes, which are integral to well integrity management. ISO 16530-1 identifies and discusses key considerations for 12 common elements, as detailed in the figure above.
Assuring well integrity comprises two main building blocks: the first is to ensure well integrity during well design and construction, and the second is to manage well integrity throughout the remaining well life thereafter ISO 16530-1 addresses the six phases of the well life cycle, and their interrelationships, as illustrated above.
This month’s video demonstrates how certainty allows for better and faster decision making and evaluate the tubing conditions of multiple sub-sea completed wells pre-abandonment.
EV was requested by a global operator to perform a multi well campaign. EV’s Optis HD Electric line camera was used to inspect the tubing conditions of multiple sub-sea completed wells pre-abandonment.
Shahril Mokhtar, Head of Completions, Petronas shares a unique case study outlining the results of their risk sharing intergrated operations and CORAL 2.0.
EV’s industry leading camera technology in partnership with an electric line tractor, allowing for real time transmission of video to surface while simultaneously tractoring downhole. This month’s video demonstrates EV’s leading technology partnerships, and how successfully integrating cameras into well intervention can save time and reduce risk for horizontal well inspections.
Maintaining and increasing production volumes from existing wells and facilities is a major priority for operators in the Asia Pacific. The region suffers from a 10% annual decline in recovery, 80% of the basin’s fields are operating in the brownfield phase and a huge volume of well stock (40%-50%) is currently shut in and not
producing.
Globally there has also been a 25% increase in the abandonment of existing wells (Almukhaitah et al, Fonoiki 2013) and a 65% decline in the oil price, resulting in a huge cut in CAPEX for new field development (U.S. Energy Information Administration EICA 2015).
An interview with Erik Dietrichson, Manager – Eastern Region Well Intervention Service, FMC Technologies
Perspectives and development of the RLWI business
Riserless Light Well Intervention or RLWI – is the term used to describe the method for performing inspection and maintenance of subsea wells from a monohull vessel by sluicing a toolstring suspended in a wireline into the subsea well under full pressure, but without using a high pressure riser. RLWI is a cost efficient method as it can be performed from monohull vessels rather than costly drilling rigs. Wireline operations are used to perform production logging by measuring the locations of liquid in-flow and water content, to install a plug to isolate intervals with high inflow of reservoir water and to re-perforate the well casing by use of explosives to establish a new production interval at a higher level. It is also possible to increase the production rate from a well by removing scale growth that will reduce the well’s flow area. Another routine operation is to install a so-called insert-down-hole-safety-valve, to replace the function of the initially installed safety valve.
Fishing is often a complex operation that can require more than a single run due to partial recovery of the fish or discovery of unexpected conditions.
This month’s video is a succession of clips recorded with EV’s Slickline Memory camera where a customer in South East Asia progressed through their recovery operation, progressively understanding the exact conditions throughout the different stages.
No special preparation was required as the jobs were run in a dry gas environment.
After a first run that accurately identified the top of wire, a wire cutter was run in hole and held up at an unexpected depth. The pin had to be sheared to release the cutter and the next camera run identified a slickline bird nest.
With this information, a significant amount of slickline was recovered and another camera was run to assess the results. The new top of fish, a slickline fishing head is clearly seen, followed by the top of a sidewall cutter.
After latching onto the sidewall cutter, another camera is run. This time, the sidewall cutter is found centred, which allowed the correct selection of fishing tools.
On recovering the sidewall cutter, another camera was run to check the condition of the wire below it. The last segment of video shows yet another slickline bird nest.
After multiple runs and several days, the customer successfully concluded the operation relying throughout on EV’s Slickline Memory Camera, a battery powered optical camera that records up to 5 hours of HD colour video images at 30 frames per second. Acquisition, as in this case, can be continuous; however the tools can also be programmed to record as many as 60 segments, an efficient and cost effective solution to diagnosing complex or changing downhole conditions over an extended period of time.
The discussions subjects covered in these postings are covered in my well integrity training courses. Go to www.internationalwellintegrity.com for more details. In this article I would like to comment on the issue of sand production and its measurement. This is a high-level view of the problem, representing the tip of the iceberg.
The technology of spectral noise logging is very powerful when in the right hands and can really provide a much direction in problem solving downhole issues. As a tool that listens for sound and does not transmit sound provides a more direct answer of downhole issues, simply relying on a pressure change OR sound of moving particles such as sand. BUT coming back to the issue of calibration, this critical element must be available, repeatable and transparent.
Your service provider should provide comprehensive details of calibrations and especially with dates, times and environmental conditions. Crucially, when calibrating the environment must be insulated from background noise, so having trucks thundering past, that vibrate and shake the work surfaces or having to tip toe past the calibration cell for fear of extraneous interference is not acceptable. But is something I have witnessed recently in one service provider facility, and questions the validity of the calibration and associated logging results.
Reviewing the service provider to ensure and validate their calibration process is key to success. Additionally, auditing of tool servicing and maintenance is crucial, especially as we are coming out of a downturn and cut backs have been severe.
Sand in the flow stream if not fully understood and correctly measured can be catastrophic. Therefore, knowledge of the sand source, the rate it is producing at and where in the well system it reaches when on production, provides a greater understanding of the problem complexity and how it might be mitigated.
A small checklist will help in the diagnostic process -:
1. Sand detection at the surface tells you straight away that you have a problem, but what is the rate of this sand production? How many pounds of sand per million standard cubic feet or thousand barrels?
2. Is the sand production rate dependant? If so, what is maximum rate the well can be produced at without sand at the surface?
3. Is there evidence in the surface equipment of sand? If so, try to sample and analyse and with a geologist determine where in the well is this coming from.
4. Measure wall thickness of elbows and compare to original construction dimensions to help measure the surface rate of metal loss
5. If an intervention is planned choose the logging company carefully, and only accept logging companies who can provide you with a numerical answer to the sand production rate. Just ticking a box to confirm its in the flow stream will not provide you with a full answer. You need to know the sand rate production versus well production rate.
6. Using slickline tools try to determine if the sump depth of the well has changed as this will suggest that the sand is dropping down the well and not all being produced to the surface.
7. Once the sand is better understood, you are then in a position to review, risk assess and determine a course of action that provides a working environment with an action plan if problems occur.
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