Improving 4-1/2" Liner Deploy Ability in 6" Horizontal Hole with Utilization of Improved Characteristics Brines and Friction Reduction Devices

2021 ◽  
Author(s):  
Kushal Gupta ◽  
Salim Abdalla Al Ali ◽  
Jeughale Ramanujan ◽  
Tetsuro Takanishi
Keyword(s):  
Drill Pipe ◽  
Oil Field ◽  
Friction Reduction ◽  
Directional Drilling ◽  
Well Bore ◽  
Drilling Mud ◽  
Horizontal Drain ◽  
Open Hole ◽  
Multiple Challenges ◽  
Horizontal Drains

Abstract A large operator of a brown field offshore in the middle east has decided to provide full lower Completion accessibility and ensure prevention of open hole collapse as it can lead to various gains throughout the life of the well. Among those benefits, it provides a consolidated well bore for various production logging & stimulation tools to be deployed effectively, as well as full accessibility, conformance control and enable to provide production allocations for each zones. However there are multiple challenges in deploying lower completion liner in drains involving multiple reservoirs and geo steered wells: Well Bore Geometry, dog legs/ tortuosity etc. & differential sticking possibilities and of course the open hole friction. Due to the size of the open hole, restricted casing design and utilization of limited OD pipes further add to the complications of deploying the Lower completion liner in such brown Field wells. This paper intend to review the multi-step methodology approach implemented in recent years by the company to effectively deploy 4-1/2" Liner in 6" Horizontal Open Hole section. Among the techniques used to assist successful deployment of lower completions are: Improving hole cleaning, ensure smooth well bore with the use of directional drilling BHA, reduction of the Open Hole friction by utilizing Lubricated brines, fit for purpose Centralizers, use of drill pipe swivel devices to increase weight available to push the liner & reduce buckling tendency. With the length of open hole laterals reaching up to 10,000 ft for 6" Lower drains, open hole drag, friction & cleanliness are major components that causes challenges in deploying the Liner till TD. The use of specially formulated brines with fixed percentage of lubricants proved to significant reduce friction compared to the drilling mud used for drilling the horizontal drain. The combination of low friction brine with proper centralization / standoff which resulted in reduced contact area with the formation has also shown good results in preventing differentials sticking while running the liner through multilayer reservoirs having significantly different reservoir pressures. Another major constrain to deploy the lower completion liner in this offshore field is the very nature of the wells being primarily workover. This involves generally Tie back liners run to shallow depths to restore the integrity of wells. This limits our ability in the selection of drill pipe that can be used as only smaller OD drill pipes and HWDP can be utilized in order to deploy the Liner to bottom. On many occasions this provides only limited weight to push the Liner down to TD and impact our ability to set the liner top packer. Drill pipe rotating swivel devices have been utilized to improve our weight availability & transferability to push the liner down and to set the liner top packers. In order to provide independent deactivation mechanism for the drill pipe swivel and to have complete success in our liner deployments, a dedicated ball activated sub was designed to deactivate the swivel acting as back up in case primary deactivation methods fails during liner setting. The combined use of all these techniques enabled the company to deploy 4.5" Liners in 6" Horizontal drains with high success in this offshore Brown Oil field of UAE. This resulted in better well construction and complete access to lower drains over the life of the wells.

ERD Drilling Record Achieved in the Gulf of Thailand with an Outstanding Drilling Efficiency

2021 ◽  
Author(s):  
Manchukarn Naknaka ◽  
Trinh Dinh Phu ◽  
Khamawat Siritheerasas ◽  
Pattarapong Prasongtham ◽  
Feras Abu-Jafar ◽  
...  
Keyword(s):  
Chemical Elements ◽  
Drilling Fluid ◽  
Drill Pipe ◽  
Oil Field ◽  
Technology Selection ◽  
Low Flow ◽  
Gulf Of Thailand ◽  
Directional Drilling ◽  
Lost Circulation ◽  
The Gulf Of Thailand

Abstract The objective of this research is to describe the methodology used to drill the most extended reach well (ERD) in the Gulf of Thailand. The Jasmine field is a mature, sophisticated, oil field with many shallow reservoir targets that require a minimum 10,000ft horizontal displacement. As such, the main challenges faced, and the novel technology applied is described in detail by this research. The research is an example of successfully drilling a challenging well, safely and efficiently. The Jasmine C – Well X, is a 3-string design structure with an 11-3/4in top hole, an 8-1/2in intermediate section, and a 6-1/8in reservoir horizontal section. Well X was constructed by utilizing an existing platform well slot. The challenge involved drilling from the top hole to the kickoff point and directional drilling away from the casing stump of the existing well to avoid any collision with nearby wells emanating from the Jasmine C platform. The 8-1/2in hole section was the most important segment as it had to reach the landing point precisely in order to start the 6-1/8in section for GeoSteering in the reservoir section. The 8-1/2in section encountered three challenges that could affect drilling efficiency.Directional Drilling – The complexities of the well profile:The method involved making well inclination (INC) lower than 82deg in the tangent interval in order to reduce the well's tortuosity as much as possible.Hole condition – Hole cleaning and fluid losses control:The method involved the use of Low Toxicity Oil Based Mud (LTOBM) CaCO3 system, the chemical elements in the drilling fluid system could help to seal the high permeable zones.Drilling Engineering – Torque and Drag (T&D) control:The method taked into account the 7in casing run to the bottom of the hole, which the casing driven system did not allow for rotation The well was completed successfully without any additional trips. A Total Depth (TD) was of 13,052ftMD was achieved to reach reservoirs at 3,260ft TVDSS. It was therefore announced in 2019 as a new ERD record for Mubadala Thailand (ERD ratio = 3.26, Directional Difficulty Index (DDI) = 6.95). The top hole and 9-5/8in casing were set in the right depth. An 8-1/2in section was accomplished on the planned trajectory with an average on bottom Rate of Penetration (ROP) at 319 ft/hr. The 6-1/8in section was drilled by geosteering to achieve sub-surface objectives. A total of 2,143ft intervals inside the reservoir was successfully achieved. While drilling, lost circulation events occured, but the mud system was conditioned with Lost Circulation Materials (LCM). Therefore, drilling performance was unaffected. Moreover, the Bit's Total Flow Area (TFA) and Rotary steering systems (RSS) flow restrictor was configured to allow directional drilling at a very low Flow rate of 470gpm. Addition, 30 joints of 5-1/2in Heavy Weight Drill Pipe (HWDP) and 39 joints of 4in HWDP were added into the Bottom Hole Assembly (BHA) to transfer string weight to drill bitsand drill to well TD. As complexities of the well profile were fully aware, the casing was runned and minimized the open hole friction until the casing was deployed successfully. In the Gulf of Thailand, drilling the longest ERD well in a shallow True Vertical Depth (TVD) was clearly groundbreaking and entailed the successful management of the key operational challenges related to identification, job planning, design, technology selection, and implementation. This research illuminates the challenges and technical solutions of long ERD well and serves as an example of what can be achieved in the region and globally.

Paradigm Shift in Completion Limits: Open Hole Gravel Pack in Highly Depleted Reservoirs Drilled with Well Bore Strengthening Technology

2021 ◽  
Author(s):  
Kevin Whaley ◽  
Phillip J Jackson ◽  
Michael Wolanski ◽  
Tural Aliyev ◽  
Gumru Muradova ◽  
...  
Keyword(s):  
Laboratory Testing ◽  
Drilling Fluid ◽  
Drilling Fluids ◽  
Well Bore ◽  
Drilling Mud ◽  
Additional Time ◽  
Sand Control ◽  
Production Wells ◽  
Open Hole ◽  
Gravel Pack

Abstract Open Hole Gravel Pack (OHGP) completions have been the primary completion type for production wells in the Azeri-Chirag-Gunashli (ACG) field in Azerbaijan for 20 years. In recent years, it has been required to use well bore strengthening mud systems to allow drilling the more depleted parts of the field. This paper describes the major engineering effort that was undertaken to develop systems and techniques that would allow the successful installation of OHGP completions in this environment. OHGP completions have evolved over the last 3 decades, significantly increasing the window of suitable installation environments such that if a well could be drilled it could, in most cases, be completed as an OHGP if desired. Drilling fluids technology has also advanced to allow the drilling of highly depleted reservoirs with the development of well bore strengthening mud systems which use oversized solids in the mud system to prevent fracture propagation. This paper describes laboratory testing and development of well construction procedures to allow OHGPs to be successfully installed in wells drilled with well bore strengthening mud systems. Laboratory testing results showed that low levels of formation damage could be achieved in OHGPs using well bore strengthening mud systems that are comparable to those drilled with conventional mud systems. These drilling fluid formulations along with the rigorous mud conditioning and well clean-up practices that were developed were first implemented in mid-2019 and have now been used in 6 OHGP wells. All 6 wells showed that suitable levels of drilling mud cleanliness could be achieved with limited additional time added to the well construction process and operations and all of them have robust sand control reliability and technical limit skins. Historically it was thought that productive, reliable OHGP completions could not be delivered when using well bore strengthening mud systems due to the inability to effectively produce back filter cakes with large solids through the gravel pack and the ability to condition the mud system to allow sand screen deployment without plugging occurring. The engineering work and field results presented demonstrate that these hurdles can be overcome through appropriate fluid designs and well construction practices.

FIELD RESULTS USING MEASUREMENT-WHILE-DRILLING DIRECTIONAL SYSTEMS IN LONG BEACH, CALIFORNIA

1981 ◽  
Vol 21 (1) ◽  
pp. 213
Author(s):  
M. Gearhart
Keyword(s):  
Drill Pipe ◽  
Oil Field ◽  
Maximum Deviation ◽  
Directional Drilling ◽  
Long Beach ◽  
Bottom Hole ◽  
Pressure Pulses ◽  
Measurement While Drilling ◽  
Degree Of Control ◽  
Mud Pressure

One of the more extensive uses of directional drilling anywhere in the world has been in the development of the East Wilmington Oil Field in Long Beach, California. The average well is deviated from vertical in excess of 50° and wells with a maximum deviation in the 70° to 80° range are not uncommon before they are dropped off to 50° or less when penetrating the completion interval. Over 780 wells have been drilled in this field to date, requiring the highest degree of control and accuracy in order to avoid intersection of other wells and to obtain proper bottom hole spacing. The Measurement-While-Drilling (MWD) directional system has been tested on several wells and proven to provide the required accuracy, along with many advantages over past methods, used in the field development.Accurate transmission by MWD of bottom-hole measurements to the surface is provided by mud pressure pulses generated in the drill pipe downhole and detected by a pressure transducer includes the means for detecting, recording and processing these pressure pulses, to translate the information from the pressure pulses to rig floor displays usable by the drilling crew.

Unlocking By-Passed Oil with Autonomous Inflow Control Devices Through an Integrated Approach

2021 ◽  
Author(s):  
Pawan Agrawal ◽  
Sharifa Yousif ◽  
Ahmed Shokry ◽  
Talha Saqib ◽  
Osama Keshtta ◽  
...  
Keyword(s):  
Continuous Production ◽  
Oil Production ◽  
Gas Production ◽  
Oil Field ◽  
Production Performance ◽  
Fluid Distribution ◽  
Flow Profile ◽  
Horizontal Drain ◽  
Control Devices

Abstract In a giant offshore UAE carbonate oil field, challenges related to advanced maturity, presence of a huge gas-cap and reservoir heterogeneities have impacted production performance. More than 30% of oil producers are closed due to gas front advance and this percentage is increasing with time. The viability of future developments is highly impacted by lower completion design and ways to limit gas breakthrough. Autonomous inflow-control devices (AICD's) are seen as a viable lower completion method to mitigate gas production while allowing oil production, but their effect on pressure drawdown must be carefully accounted for, in a context of particularly high export pressure. A first AICD completion was tested in 2020, after a careful selection amongst high-GOR wells and a diagnosis of underlying gas production mechanisms. The selected pilot is an open-hole horizontal drain closed due to high GOR. Its production profile was investigated through a baseline production log. Several AICD designs were simulated using a nodal analysis model to account for the export pressure. Reservoir simulation was used to evaluate the long-term performance of short-listed scenarios. The integrated process involved all disciplines, from geology, reservoir engineering, petrophysics, to petroleum and completion engineering. In the finally selected design, only the high-permeability heel part of the horizontal drain was covered by AICDs, whereas the rest was completed with pre-perforated liner intervals, separated with swell packers. It was considered that a balance between gas isolation and pressure draw-down reduction had to be found to ensure production viability for such pilot evaluation. Subsequent to the re-completion, the well could be produced at low GOR, and a second production log confirmed the effectiveness of AICDs in isolating free gas production, while enhancing healthy oil production from the deeper part of the drain. Continuous production monitoring, and other flow profile surveys, will complete the evaluation of AICD effectiveness and its adaptability to evolving pressure and fluid distribution within the reservoir. Several lessons will be learnt from this first AICD pilot, particularly related to the criticality of fully integrated subsurface understanding, evaluation, and completion design studies. The use of AICD technology appears promising for retrofit solutions in high-GOR inactive strings, prolonging well life and increasing reserves. Regarding newly drilled wells, dedicated efforts are underway to associate this technology with enhanced reservoir evaluation methods, allowing to directly design the lower completion based on diagnosed reservoir heterogeneities. Reduced export pressure and artificial lift will feature in future field development phases, and offer the flexibility to extend the use of AICD's. The current technology evaluation phases are however crucial in the definition of such technology deployments and the confirmation of their long-term viability.

Pipe stick problems of deep well drilling

2021 ◽  
Vol 66 (05) ◽  
pp. 192-195
Author(s):  
Rövşən Azər oğlu İsmayılov ◽  
Keyword(s):  
Drilling Fluid ◽  
Drill Pipe ◽  
Drill String ◽  
Differential Pressure ◽  
Drilling Mud ◽  
Fluid Circulation ◽  
Well Drilling ◽  
Deep Well ◽  
Pressure Pipe ◽  
Bottomhole Pressure

The aricle is about the pipe stick problems of deep well drilling. Pipe stick problem is one of the drilling problems. There are two types of pipe stick problems exist. One of them is differential pressure pipe sticking. Another one of them is mechanical pipe sticking. There are a lot of reasons for pipe stick problems. Indigators of differential pressure sticking are increase in torque and drug forces, inability to reciprocate drill string and uninterrupted drilling fluid circulation. Key words: pipe stick, mecanical pipe stick,difference of pressure, drill pipe, drilling mud, bottomhole pressure, formation pressure

scholarly journals EXPERIENCE IN CONSTRUCTION OF HORIZONTAL WELLS AT THE KOSHILSKOYE OIL FIELD

2018 ◽  
pp. 34-37
Author(s):  
N. A. Aksenova ◽  
E. Yu. Lipatov ◽  
T. A. Haritonova
Keyword(s):  
Horizontal Wells ◽  
Cost Effective ◽  
Oil Field ◽  
Drilling Mud ◽  
Environmentally Safe

The article presents the experience of drilling horizontal wells at the Koshilskoye oil field in Jurassic sediments (UV1 formation) with application of environmentally safe emulsion drilling mud system BARADRIL-N XP-07 which has proved cost-effective.

scholarly journals Research on Mud Pulse MWD Device for Mines

2021 ◽  
Vol 248 ◽  
pp. 03050
Author(s):  
Gao Jun
Keyword(s):  
Signal Transmission ◽  
Drill Pipe ◽  
Pulse Signal ◽  
Pulse Method ◽  
Directional Drilling ◽  
Transmission Distance ◽  
Signal Encoding ◽  
Measurement While Drilling ◽  
Working Principle ◽  
Encoding Method

As the core accoutrement of directional drilling construction, the measurement while drilling (MWD) device can be divided into three types due to the different data transmission methods: wired, mud pulse and electromagnetic wave. This paper used the mud pulse method to develop a mud pulse MWD device for mines, and the working principle of the mud pulse signal transmission, the signal encoding method and the structure of the device were described. Experimental research showed that the mud pulse wireless MWD device had the advantages of long transmission distance and strong working stability. At the same time, the device was not restricted by the drill pipe during operation, which could be combined with sliding orientation and rotary feed, and had great promotion and application value.

Unusual Corrosion of a Drill Pipe in Newly Developed Drilling Mud during Deep Drilling

CORROSION ◽  
1999 ◽  
Vol 55 (7) ◽  
pp. 706-713 ◽  
Author(s):  
Y. Tomoe ◽  
M. Shimizu ◽  
Y. Nagae
Keyword(s):  
Drill Pipe ◽  
Drilling Mud ◽  
Deep Drilling

FIGHTING FRACTURED FLAMINGO—LESSONS FROM RAMBLER-I, TIMOR SEA

1995 ◽  
Vol 35 (1) ◽  
pp. 655
Author(s):  
D. C. Lowry
Keyword(s):  
Lessons Learned ◽  
Open Fractures ◽  
Thick Section ◽  
Well Bore ◽  
Drilling Mud ◽  
Lost Circulation ◽  
Evaluation Strategies ◽  
Timor Sea ◽  
The Right ◽  
Exploration Well

Exploration well Rambler-1, located in the Timor Sea, presented an unusual set of engineering and evaluation problems when drilling a thick section of Flamingo Group (Jurassic–Cretaceous). The well encountered normally pressured open fractures where drilling mud was lost, and at least two mildly overpressured fractures that flowed small quantities of gassy oil into the well-bore. In these circumstances it was difficult to find the right combination of casing, mud density, cement plugs and lost circulation material to drill the well in a controlled and efficient manner.Fine grained sandstone in the Flamingo Group gave moderate mud log shows and two cased-hole RFTs recovered oil. However, cased-hole DSTs of the same intervals recovered only small volumes of filtrate. This remarkable behaviour is attributed to the RFTs recovering oil from porous cement that had been impregnated with oil from the lower of the overpressured fractures.Any future wells drilled near the axis of the Sahul Syncline are likely to encounter similar problems and awareness of the lessons learned in Rambler–1 can improve drilling and evaluation strategies.

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