Layer | Fill | Outline |
---|
Map layers
Theme | Visible | Selectable | Appearance | Zoom Range (now: 0) |
---|
Fill | Stroke |
---|---|
Collaborating Authors
Results
_ This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper SPE 216249, “Digital Innovation of Well-Construction Process in Ecuador Through Rig Automation,” by Karen Peña, Kevin Etcheverry, and Hugo Quevedo, SPE, SLB, et al. The paper has not been peer reviewed. _ Artificial intelligence (AI)-based digital drilling technology was implemented in two mature fields in Ecuador that represent 33% of the country’s oil production. The drilling campaign’s main strategy included the deployment of a novel automation solution on two rigs, resulting in the optimization of the well-construction process. In the complete paper, the authors present the results of implementation of a rig-automation solution applied to 20 wells in 2022. Scope of the Digital Solution The authors detail the validation, optimization, and implementation of a drilling software to automate work flows and the installation and commissioning of associated hardware components. The following key indicators and objectives were established: - Validation of drilling-software work flows - Achievement of a 75% average in automation control - Improvement of rate of penetration (ROP) by 5% - Reduction of pre- and post-connection times by at least 30% - Real-time tuning of parameters - Training of all personnel involved in the use of the drilling-software package - Installation and commission of hardware components Drilling-Software Implementation The digital solution is an advanced software system that brings automation capabilities to drilling rigs, analogous to the different levels of automation found in automobiles. By drawing a parallel to car automation, one can better understand the system’s functionality and benefits. Level 1 consists of task automation, comparable to automatic driving features such as cruise control. In this context, the drilling software takes on the role of automating specific tasks within the drilling process. Level 2 involves process automation, similar to a car’s ability to autonomously park itself. The digital solution automates selected processes in drilling operations that enable efficient and precise execution. Level 3 encompasses adaptive automation, akin to a self-driving car that dynamically adapts to its surroundings. The drilling software continuously analyzes the real-time conditions of the wellbore and suggests optimal drilling parameters based on proprietary algorithms that leverage the well-known DeTournay model principle. The drilling software actively controls four key rig machines: the drawworks, topdrive, automated driller, and mud pumps. The solution adjusts drilling parameters intelligently, optimizing the drilling process and improving overall efficiency and drilling stability.
- Well Drilling > Drilling Equipment (1.00)
- Well Drilling > Drilling Fluids and Materials > Drilling fluid management & disposal (0.69)
- Data Science & Engineering Analytics > Information Management and Systems > Artificial intelligence (0.69)
- Well Drilling > Drilling Operations > Drilling optimization (0.51)
Characterization and Performance Evaluation of Modified Apatite Ore as a New Acid-Soluble Weighting Agent for Drilling Fluids
Zhao, Xin (School of Petroleum Engineering, China University of Petroleum (East China) (Corresponding author)) | Zhang, Heng (School of Petroleum Engineering, China University of Petroleum (East China)) | Wang, Shuai (School of Petroleum Engineering, China University of Petroleum (East China)) | Su, Wenzhi (School of Petroleum Engineering, China University of Petroleum (East China)) | Sun, Hao (School of Petroleum Engineering, China University of Petroleum (East China)) | Ren, Xiaoxia (School of Science, Qingdao University of Technology (Corresponding author))
Summary Drilling in oil and gas reservoir formations requires the solid weighting agent used in drilling fluids to have good acid solubility to facilitate plugging removal in subsequent operations. Limestone is the most commonly used acid-soluble weighting agent, but its low density and significant thickening effect lead to a low weighting limit. To achieve control of drilling fluid density, rheology, sag stability, and acid solubility, the feasibility of using apatite (AP) ore as an acid-soluble weighting agent for drilling fluids has been discussed after it was modified by the nitrogen-containing organic polybasic phosphonic acid sodium salt. The basic characteristics of AP and modified AP (MAP) were analyzed. After that, the rheological, filtration, and sag stability properties of MAP-weighted water-based drilling fluids with densities of 1.2 g/cm and 1.6 g/cm were evaluated, and acid solubility, filter-cake permeability, core permeability damage, and plugging removal tests by acid solutions were performed to evaluate the formation protection effect. The results show that the density of AP is 2.98 g/cm, and the main component is hydroxyapatite. Its negative electricity and hydrophilicity were enhanced after surface modification, so its dispersion stability in water was enhanced, thereby improving the rheology, filtration, and sag stability properties of the MAP-weighted drilling fluid. The solubility of MAP in 10% HCl solution reached 90.13%, and the core contamination experiments show that after being soaked in HCl solution, the return permeability of contaminated cores reached higher than 90%, indicating that the MAP invading the core can be efficiently dissolved and removed in the acidic working fluids used in the subsequent completion and stimulation operations, thus effectively protecting the reservoir formation. The properties of MAP are superior to those of limestone, and it can be used as a new acid-soluble weighting agent for drilling fluids, considering both drilling fluid performance regulation and reservoir formation protection.
- North America (0.93)
- Asia > China > Shandong Province (0.28)
- Geology > Mineral (0.98)
- Geology > Rock Type > Sedimentary Rock > Carbonate Rock > Limestone (0.49)
Experimental Study on Permeability and Gas Production Characteristics of Montmorillonite Hydrate Sediments Considering the Effective Stress and Gas Slippage Effect
Wu, Zhaoran (School of Vehicle and Energy, Yanshan University) | Gu, Qingkai (School of Vehicle and Energy, Yanshan University) | Wang, Lei (School of Vehicle and Energy, Yanshan University) | Li, Guijing (School of Vehicle and Energy, Yanshan University) | Shi, Cheng (School of Vehicle and Energy, Yanshan University) | He, Yufa (State Key Laboratory of Natural Gas Hydrate) | Li, Qingping (State Key Laboratory of Natural Gas Hydrate) | Li, Yanghui (Key Laboratory of Ocean Energy Utilization and Energy Conservation of Ministry of Education, Dalian University of Technology (Corresponding author))
Key Laboratory of Ocean Energy Utilization and Energy Conservation of Ministry of Education, Dalian University of Technology Summary Gas permeability in hydrate reservoirs is the decisive parameter in determining the gas production efficiency and gas production of hydrate. In the South China Sea (SCS), the gas flow in tight natural gas hydrate (NGH) silty clay reservoirs is significantly affected by the gas slippage effect and the effective stress (ES) of overlying rock. To improve the effectiveness of hydrate exploitation, it is necessary to understand the influence of gas slippage in hydrate reservoirs on the permeability evolution law. For this paper, the gas permeability characteristics and methane production of hydrate montmorillonite sediments were studied at different pore pressures and ESs. Experimental data revealed that the gas permeability of montmorillonite samples before methane hydrate (MH) formation is seriously affected by the Klinkenberg effect. The gas permeability of montmorillonite sediments before hydrate formation is generally smaller than that after hydrate formation, and the gas slippage effect in the sediments after hydrate formation is weaker than that before hydrate formation. With the change in ES, the intrinsic permeability of sediment has a power law relationship with the simple ES. As pore pressure decreases and MH decomposes, montmorillonite swelling seriously affects gas permeability. However, the gas slippage effect has a good compensation effect on the permeability of montmorillonite sediments after MH decomposition under low pore pressure. The multistage depressurization-producing process of MH in montmorillonite sediments is mainly 3 MPa depressurization-producing stage and 2 MPa depressurization-producing stage. In this paper, the influence mechanism of gas slippage effect of hydrate reservoir is studied, which is conducive to improving the prediction accuracy of gas content in the process of hydrate exploitation and exploring the best pressure reduction method to increase the gas production of hydrate in the process of exploitation. Introduction As one of the most prospective clean energy sources in the 21st century, NGH mainly exists in permafrost and continental margins of the world's oceans (Sloan Jr. and Koh 2007). MH is the most important component of NGH. MHs are ice-like crystalline compounds in which the host methane molecule is surrounded by a cage of water molecules (Sloan 1998; Li et al. 2023).
- North America > United States (1.00)
- Europe > Norway > Norwegian Sea (0.64)
- Asia > China > Liaoning Province > Dalian (0.24)
- Research Report > New Finding (0.83)
- Research Report > Experimental Study (0.64)
- Asia > China > South China Sea > Yinggehai Basin (0.99)
- Asia > China > South China Sea > Qiongdongnan Basin (0.99)
- South America > Falkland Islands > South Atlantic Ocean > South Falkland Basin > Stokes Prospect > Darwin Formation (0.94)
Engineered Ultra-Low Invasion Loss Control Solution Allows Circulation, Ensuring Cement Placement and Zonal Isolation in Liner Cementing Jobs and Through Coiled Tubing – Case Studies
Fazal, Muhammad Adnan (Sprint Oil and Gas Services FZC) | Ahmad, Syed Hamza (Sprint Oil and Gas Services FZC) | Yousuf, Arif (Sprint Oil and Gas Services FZC) | Rehman, Aziz ur (Sprint Oil and Gas Services FZC) | Noor, Sameer Mustafa (Oil & Gas Development Company Limited) | Nazir, Irfan (Oil & Gas Development Company Limited)
Abstract The conventional loss cure techniques are largely reactive and include addition of coarse grade particle, fibrous material and other viscous pills that are lost into formation during loss cure attempts. Being highly invasive, these loss cure solutions block pore throats and line producing fractures causing considerable formation damage and loss of net asset value. Moreover, these techniques pose additional challenges while placing thru slim liners and coiled tubing (in rigless applications) due to elevated risk of getting the circulation ports plugged. Moreover, during the era of technological revolution and decarbonization, an effective and efficient solution aids to promote the practices producing low carbon emission. The proactive wellbore shielding loss cure is a particle size distribution-based LCM solution having excellent fluid loss properties and exhibiting low permeability barrier at the fluid-rock interface. The low permeable shielding effect offers less invasion across a broad range of pores (1microns to 4,000microns) and thereby protecting formation from any permanent impairment. The solution covers the wide range applications of loss cure throughout well life ensuring zonal isolation and saving significant rig time. Customized particle size distribution does allow LCM solution to be pumpable thru liner complying the allowable particle sizes (less than 1,000microns) and concentrations (upto 18 lbs/bbl) and for coiled tubing specialized applications with allowable particles size of 100 microns while maintaining rheological properties (Fluid Loss<50 ml/30 min, 5lbs/100ft2>Ty<10lbs/100ft2 & PV<90 cp). This paper demonstrates the working principle and practical applications of engineered solution for loss cure and successfully achieving zonal isolation in 7" liner being placed as pre-cement spacer in naturally fractured formation. The wellbore shielding pre-cement spacer ensured the cement rise above loss point thus achieving zonal isolation in partial to complete losses environment and helps in minimizing formation's impairment. The same approach was adopted to cure losses in rigless with coiled tubing in both carbonate and sandstone reservoirs for well killing and zonal isolation without plugging the CT BHA and circulation ports while complying design requirements.
- South America (0.68)
- Asia > Middle East (0.28)
- Well Drilling > Wellbore Design > Wellbore integrity (1.00)
- Well Drilling > Pressure Management > Well control (1.00)
- Well Drilling > Drilling Operations (1.00)
- (8 more...)
Abstract The Dilemma of Limestone Formations is their temperamental nature. The same conductivity that threatens with Loss also promises production and at the same time deceives log outputs. Presence of conductive fractures is characteristic of these carbonates and even if the operator does drill past these thief zones via controlled drilling ECDs and LCM loaded systems, the hazard is never eliminated. One of the poorest timing for this menacing loss to resurface is during cementing of these reservoir carbonate sections, when ECDs tend to rise as soon as the cement slurry dares rise above the loss zone. Conventional LCMs are not the candidate for formation strengthening and cementing every loss zone can be rather tiresome for the drilling time-depth curves, not to forget damaging to the reservoirs. So, the approach to case these conductive carbonates while maintaining their conductivity remains a work in progress for the cementing technical community. This paper suggests not to merely drill through or fight against the loss but to mould the formation properties to operator's requirements. The stress caging technique may be one of the key puzzle elements to strengthen fractured limestones and their successful cementing.
- North America > United States (0.47)
- Asia > Pakistan (0.33)
- Europe > Norway > Norwegian Sea (0.24)
- Geology > Rock Type > Sedimentary Rock > Carbonate Rock > Limestone (0.50)
- Geology > Geological Subdiscipline (0.48)
Drilling and Well Construction in Lean Clearances in Northern Region of Pakistan
Iftikhar, Ali (Mari Petroleum Company Limited, Islamabad, Pakistan) | Nasrumminallah, Muhammad (Mari Petroleum Company Limited, Islamabad, Pakistan) | Rasheed, Hassaan (Dowell Schlumberger, Islamabad, Pakistan) | Sabir, Shahid Majeed (Weatherford Oil Tools ME, Islamabad, Pakistan) | Sharif, Yasir (Weatherford Oil Tools ME, Islamabad, Pakistan)
Abstract Subject well is an exploratory well with a target depth of +/- 6000M, in one of the most challenging northern region of Pakistan. Well has multiple challenges with regards to drilling and well construction the least to mention are losses, borehole instability, intercalated formations, with steep dips along with a fault. Lean clearances in a five Casing Strings well construction were a requirement to isolate the problematic zones for safe drilling, this included running of longest 16" Liner for the first time in Pakistan, borehole enlargement of 14 3/4" to 16", later on running of 13 5/8" Flush x 13 3/8" coupled connection casing with narrow annular clearance, with customized Cementing Job to avoid surging. Running of 16" liner, drilling and construction of next section called for robust technical applications that includes drilling with aerated mud, running of 16" Liner with liner hanger for the first time in Pakistan, borehole enlargement while overcoming the various challenges as various formations (limestone, Sandstones, Clays) were drilled and later enlarged using hydraulic Under Reamer. Fit for purpose mud was used while drilling and further optimized to solid free for the smooth running of 13 5/8" × 13 3/8" Casing through lean clearance of 16" Liner. Casing running strategy has been devised to avoid Surge to formation at the same time ensuring it gets to bottom without any held up. The objectives of the section were met successfully. The paper will serve as a platform for other Operating companies in Pakistan to benefit from the lessons learnt and best drilling practices
- Well Drilling > Drilling Fluids and Materials > Drilling fluid selection and formulation (chemistry, properties) (0.90)
- Well Drilling > Drilling Operations > Running and setting casing (0.71)
- Well Drilling > Casing and Cementing > Casing design (0.70)
- Well Drilling > Drillstring Design > Torque and drag analysis (0.69)
Step-Change in Cement Design Assures Well Integrity Under Dynamic Stress
Mahmood, Ahmad A. (Schlumberger, Islamabad, Pakistan) | Jan, Usman A. (Schlumberger, Islamabad, Pakistan) | Khan, Anum Y. (Schlumberger, Islamabad, Pakistan) | Rasheed, Hassaan (Schlumberger, Islamabad, Pakistan) | Salazar, Jose (Schlumberger, Islamabad, Pakistan) | Shah, Khurram A. (MOL, Islamabad, Pakistan) | Khan, Shahjahan (MOL, Islamabad, Pakistan)
Abstract The Kohat Plateau in Pakistan features major Gas and Condensate producing fields with majority of the blocks owned and operated by two of the country's biggest E&P Operators. Operators are known to frequently encounter severe drilling challenges, and over time, have devised certain technology solutions that have helped curtail the major drilling challenges to a good extent, helping improve the time and cost expended in reaching the target depths. However, the problems arising after the Drilling cycle – foremost being Sustained Casing Pressure (SCP) – require expensive remedial treatments and loss of production; this paper presents a solution to this particular challenge of SCP including in-depth cause analysis, treatment design and implementation. In the analysis stage, the drilling data of wells experiencing SCP in one of the Casing annuli was reviewed to pinpoint possible areas of compromised well integrity. It was observed that sections having good Cement bonds and sufficient Top of Cement in the annulus also became compromised over time, indicating operations conducted after the drilling phase could be responsible for the annular fluid migration, and hence SCP. It must be noted that extensive drill-stem tests to assess the reservoir economics as well as production pressures generate significant dynamic stress on the well structure. Through the use of custom stress-analysis software for annular Cement, it was concluded that it is this stress that causes the primary isolation of the constructed well, the annular Cement, to fail allowing annular migration of formation fluids. A new class of stress-resistant, auto-repair Cements was seen to resist any mechanical failure under stress enabling Operators to drill wells with lasting structural integrity. Mechanical properties including Young's Modulus, Poisson Ratio and Annular Expansion co-efficient were analyzed to design a Cement system capable of withstanding the applied stress. The first in-country application was conducted as the Intermediate-section Cementing in a new well. The system exhibited good isolation with average 10mV amplitude (free pipe amplitude 51 mV) in Cased Hole bond logs and no annular pressure is observed till date in the section more than 02 years after the primary cementing operation. This design approach was subsequently extended to other fields, with successful applications that reduced, and in certain cases, eliminated the need for remedial work. By presenting a detailed field application of flexible and self-healing Cement, the paper puts forth a general, stepwise approach for the selection of a Cement design that promises lasting annular isolation and minimizes the risk of communication behind the casing.
- Asia > Pakistan (0.51)
- North America > United States > Texas (0.28)
IADC Code Upgrade: Interpretation of Surface and Downhole Data to Support Drilling Forensics
Watson, W. (Shell) | Witt-Doerring, Y. (Robert Gordon University (Corresponding author)) | Sugiura, J. (Halliburton) | Pastusek, P. (Sanvean Technology) | Daechsel, D. (Exxon) | Vallet, L. (Shell) | Amish, M. (Schlumberger) | Oluyemi, G. (Robert Gordon University)
Summary This paper establishes drilling surveillance interpretation and monitoring techniques for digital drilling data which can be used to support drilling forensics and improve drilling performance. One significant advancement in the last 20 years has been the widespread availability and use of sensors to monitor all aspects of the drilling process. The majority of sensors will take surface and downhole data at several hundred samples per second, process the data, and store a record at one sample per second. The data from these sensors are collated and processed using some form of electronic data recording (EDR) system. The information is subsequently displayed in real time and stored for off-site transmittal. This paper extensively evaluates the impact on drilling performance due to how data from such sensors are collected and processed and the information is displayed. A number of observations are investigated, analyzed, and explained identifying how data quality, consistency, frequency, sensor errors, and data artifacts can skew the displayed results. This can critically impact the drilling forensic analysis and subsequent interpretation. Failing to account for these data quality issues in real time may mask drilling dysfunction, causing accelerated damage to the drill bit and drilling assembly. This paper also aims to highlight techniques for displaying and interpreting drilling data to enhance drilling performance as well as diagnose dysfunction during reviews of historic wells. Understanding these limitations in advance and incorporating them in a team’s surveillance strategy can help with the diagnosis of drilling dysfunction and aid performance improvement. These recommended practices have been developed to offer a foundation for drilling surveillance, interpretation, and monitoring as well as training for the industry. They have been created such that they can grow organically and may be used for developing subsequent industry publications. The work described in this paper is part of a joint International Association of Drilling Contactors (IADC)/Society of Petroleum Engineers (SPE) industry effort to revise the IADC dull-grade process.
- Europe (1.00)
- North America > United States > Texas (0.94)
- North America > United States > Texas > Permian Basin > Delaware Basin (0.99)
- North America > United States > New Mexico > Permian Basin > Delaware Basin (0.99)
Summary Due to the nature of drilling operations, there are several companies collecting data at the rig. The data acquisition system of each company applies its own timestamp to the data. Subsequent aggregation of data (for example, in a data repository) relies on synchronized timestamps applied to the different data sources to correctly collate the data. Unfortunately, synchronized timestamping is rarely achieved. In this paper, we document the different sources of errors in timestamping of data and provide guidelines to help mitigate some of these causes. There are many reasons for the unsynchronized timestamping of data from different sources. It can be as simple as clock synchronization at the rig; each data-providing or -producing company has an independent clock. It can also be due to where the timestamp is applied, for example, at the data source or on data reception. Additionally, it can be due to how the timestamp is applied—at the start of the sampling interval, the midpoint, or the end. Some of the communication methods used at the wellsite, such as mud pulse telemetry that is used to transmit downhole measurements to the surface, have a high, nonstationary latency and the actual acquisition time may vary significantly from the received time. Not correcting the reception time for the transmission delay can result in erroneous timestamping of downhole-acquired data. Timestamping of derived data (data computed from two or more sources) is problematic if the data sources are unsynchronized. Synchronization of clocks within the data acquisition network is therefore extremely important. The resolution of time synchronization depends on purpose; motion control of the rig equipment (for example, the hoist) demands high-resolution timekeeping. However, for the purposes of timestamping acquired data, synchronization to a network time server (a computer with access to a reference clock that distributes the time of day to its client computers over a network) with a resolution of 1 millisecond is sufficient. The issue is agreeing on the common source of time (the reference clock) and agreeing on the passage of time signals through network firewalls. Timestamping is a more involved matter, calling for agreement on standards and, if possible, a computer-interpretable description of the time-related information associated with real-time data. In this paper, we describe in some detail sender vs. receiver timestamping, the downhole to surface timestamp chain, and timestamping of derived data. Systems automation and interoperability at the rigsite—allowing plug-and-play access to equipment and applications—rely on an agreed-upon network synchronization scheme and timestamping methods and standards. Indeed, designing applications that must handle uncertain time adds considerable complexity and cost, not to mention the impact on accuracy and reliability. We present an ordered approach (or guidelines) to a quite resolvable problem. In the last section of the paper, we use a semantic network approach (a semantic graph) to describe relationships for clock synchronization and timestamping (the guidelines and recommendations developed in this paper). A complete description of the semantic vocabulary is provided in an appendix. This makes these guidelines and recommendations digital—able to be interpreted by digital devices—and therefore implementable and auditable.
- Europe (1.00)
- North America > United States > Texas (0.68)
- Well Drilling > Drilling Measurement, Data Acquisition and Automation > Measurement while drilling (1.00)
- Data Science & Engineering Analytics > Information Management and Systems > Artificial intelligence (1.00)
- Well Drilling > Drilling Fluids and Materials > Drilling fluid management & disposal (0.93)
Summary In the placement process of the cement slurry, treatment fluids such as the spacer are pumped ahead of the cementitious slurry to minimize the contamination of the slurry by drilling fluid and ensure superior bonding to the casing and formation. The spacer discussed in this work can harden with time and act as a settable spacer. This characteristic can be an advantage for well integrity if some spacer pockets are left in the annulus. Rheological compatibility of different mixtures of the spacer with oil-based drilling fluid (OBDF) has been studied using a rheometer, and the resulting R-factor, which indicates the degree of compatibility between fluids, has been calculated. An increase in the flow curve was observed for the mixture of the fluids. However, based on the R-index, these fluids are compatible with displacement in the wellbore. A nonionic surfactant, typically used in conventional spacers acting as an emulsifier and a water-wetting agent, was used in the hardening spacer design. The results show that the addition of OBDF to hardening spacer containing surfactant can increase viscoelasticity. Hardening spacer containing surfactant can successfully reverse the OBDF emulsion. By performing a small-scale mud displacement experiment, we observed that surfactant can improve the wall cleaning efficiency of the spacer while having minimal impact on the bulk displacement.
- Europe (1.00)
- North America > United States > California (0.28)
- Research Report > New Finding (0.48)
- Research Report > Experimental Study (0.48)