Increasing Operational Efficiency in Extended Reach, Offshore Wells – A Case Story from Middle East

2016 ◽  
Author(s):  
Anthony MacLeod
Keyword(s):  
System Integration ◽  
Cost Effective ◽  
Lessons Learned ◽  
Operating Efficiency ◽  
Coiled Tubing ◽  
Electric Line ◽  
Release Device ◽  
Integration Test ◽  
Closed Position ◽  
Shifting Profile

ABSTRACT Objective A case story from ME will be presented covering an extreme extended reach, offshore well. Any increase to operating efficiency can save time and increase production. In this case story two SSD's were opened in a single run on e-line, an outstanding achievement due to the ID restrictions and extended reach of the well. The paper will discuss the planning, the operation, the achievements and the lessons learned. Methods, Procedures, Process This well was recently worked over, retrieval and new installation of upper and lower completion. Due to the well going on total losses during the workover, a closed system was deployed to enable the operator to set the hydraulic packers. The packer is utilized for isolation between two zones, with each zone having two SSD's in which one SSD per zone was required to be opened to allow access to the formation. From day one of planning the primary solution for this intervention was an electric over hydraulic toolstring made up of five tools, a 218 electric release device, 218 CCL for correlation, a 218 tractor for conveyance, a 218 stroker for the mechanical manipulation and a 218 key to address the shifting profile in the SSD (toolstring). A slimhole toolstring was required due to the packer ID of 2.81" The operator was using the service provider for other interventions on this workover campaign and decided to challenge them with opening two SSD's in one run while not shifting the adjacent SSD's. The challenging underlying economics of the industry today has created a powerful driver for operators to find more efficient, cost effective and safer intervention methodologies. The operation covered in this case provided just such improvements to the client: by utilizing electric line intervention tools the operator negated the requirement for a large footprint coiled tubing intervention. Results, Observations, Conclusions A System Integration Test (SIT) was completed onshore prior to mobilization, where multiple shifts were successfully executed on a 90° deviated pipe using a single set of shifting key pads. Test results were then repeated offshore, completing two interventions in a single run. The SSD's were successfully opened at ~12,000 ft MDRT and ~8,000 ft MDRT, respectively while leaving the two adjacent SSD's in the closed position. Results, client objective was 100% achieved using only electric line, enabling the client to move forward with similar well designs having the confidence that a safe, reliable electric line solution is locally available. Additional results include reduced HSE risks as the e-line approach eliminated the use of a heavier CTU. Further contributing to the HSE benefits on this operation, only 6 persons were needed on site and no heavy lifts were required. The paper will also cover some lessons learned as debris in the profile and tubing caused some challenges. Novel/Additive Information This operation shows how the industry is constantly trying to improve on existing methods in order to be more efficient, safe and cost effective.

Effective Zonal Isolation Straddle Deployment in a Slim Deviated Well using Electric Line Tractor / Stroker Combination

2021 ◽  
Author(s):  
Muhammad Nabil Ghazali ◽  
Kasim Selamat ◽  
Stuart William Murchie ◽  
Rosano F. Sosrohadisewoyo ◽  
Matthieu Billaud
Keyword(s):  
System Integration ◽  
Lessons Learned ◽  
Sand Production ◽  
Well Production ◽  
Well Completion ◽  
Electric Line ◽  
Optimal Capacity ◽  
Integration Test ◽  
Pulling Forces ◽  
Well Trajectory

Abstract Due to sand production coming from the upper zone of a multizone monobore gas well completion, the well production had to be choked back to a flow rate below the well's maximum sand free rate (MSFR). This resulted in suboptimal production. A straddle packer assembly was installed across this upper zone, which isolated the sand production and, therefore, enabled the choke to be removed and the well production to be increased to its true, optimal capacity. Several previous attempts to deploy and install the straddle components at their required depth using the prescribed slickline deployment method proved unsuccessful, because of hold ups that occurred while running in hole—due to a well trajectory of 72 degrees deviation and 4.579 deg/100 ft dog leg severity, coupled with the small tubing inside diameter (ID) associated with the slim 3 ½ in. completion. Furthermore, it was found that insufficient forces were available via slickline deployment to execute the related stabbing, setting and release actions required during in-well straddle component installation, because of the limited jar down weight available and safe working load limits on the slickline at the setting depth. As a result, a slim 2 ⅛ in. electric line tractor was utilised, in combination with a 2 ½ in. electrohydraulic linear actuator (stroker). The tractor conveyed the various straddle packer and spacer elements (straddle tubes) to depth and the stroker installed these components in the well to confirm their engagement and to ensure their controlled and confirmed release. Being bi-directional by design, the stroker provided both the upward and downward forces required for component installation—stabbing, setting, and pin shearing to release. The stroker was also available in the toolstring in case of any inadvertent tool sticking encountered while running in hole due to the well trajectory and produced sand debris. A system integration test (SIT) was meticulously planned and executed by the relevant operator and service company representatives before the operation. It was used to confirm the stroker's capability to stab and set the straddle tube into the lower packer and to shear the running tool used to install the straddle tubes and upper packer. This included the installation of straddle tubes into the lower packer section, done in a horizontal configuration and completed using higher setting and pulling forces than those expected during the actual job to ensure more than adequate forces would be available. The operation was executed successfully following the newly defined program, applying the lessons learned from the SIT. A total of four runs were carried out using the combined tractor/stroker deployment string configuration without any in-well deployment issues—the straddle component installation completed with 100% operational efficiency. Following this, the well was put back onto production and the production rate increased from approximately 1 million standard cubic feet per day (MMscf/D) to 3 MMscf/D, with no sand production observed at surface. Having not been done before, this methodology proved to be a successful option for the operator for straddle packer assembly deployment in deviated slim wells.

Efficiently Shifting Sliding Sleeves in Extended Reach Horizontal Wells with Electric-Line: A Case Study

2021 ◽  
Author(s):  
Thomas Mauchien ◽  
Sharat Kishore ◽  
Amanda Olivio ◽  
Mostafa Ahmed
Keyword(s):  
Real Time ◽  
System Integration ◽  
Horizontal Well ◽  
Maximum Flow ◽  
Horizontal Wells ◽  
Coiled Tubing ◽  
Electric Line ◽  
Closed Position ◽  
First Time

Abstract Traditional intervention operations with coiled tubing (CT) in extended reach horizontal wells might be difficult to access due to lockup from frictional forces and operational inefficiencies. Using conventional shifting tools requires multiple runs to shift open and close multiple sliding sleeve doors (SSD). This paper is a case study of an electric-line powered shifting intervention operation to shift open an SSD, circulate fluids though the sleeve and into the annulus, and then close and repeat this for another SSD in a long horizontal well—all in a single run. The paper discusses the different methods that can be used to efficiently seek and latch onto the shifting profiles using a tractor, wireline cable, and the shifting tool itself with an inchworm motion. The electric-line shifting tool monitored and verified the opening and closing of the sleeves in real time using its onboard sensors. These techniques were effectively deployed in multiple wells that required the annulus to be displaced with fluid after running smart completions. The completions were installed in the well with the SSDs in a closed position, and the shifting intervention consisted in opening the SSD, pumping fluids through the sleeve, and closing the SSD. The tool was anchored in place in the wellbore during the entire circulating operation, and the SSD was subsequently closed. This operation was then repeated on the second SSD in the wellbore, and the entire operation was completed in a single run. Also, no additional caliper run was needed as the shifting tool verified the position of the SSDs. These methods were used in a long horizontal well with the help of real-time measurements. The tool measurements identified if the SSDs were in open or closed position or anywhere in-between. The shifting tool provided confirmation via its measurements that the sleeve was not partially open. This was particularly important when pumping fluid through the annulus to achieve the maximum flow through the sleeve. Operating using electric-line was extremely efficient and eliminated the need to perform multiple runs, thus achieving time savings on the rig. This is the first time that a paper discusses the different seek methods that can be used for carrying out a electric-line mechanical intervention operation. It represents a novel method using a shifting tool as a caliper to probe and measure the completion inner diameter changes while seeking for the profile. It provides a valuable method for reliably and confidently locating and latching onto a shifting profile. Finally, this is the first time that a paper correlates the theoretical mechanics of shifting a sliding sleeve with consistent results from system integration tests and downhole measurements from the real job.

Advance Live-Well Deployment System in Caspian Sea Wells

2021 ◽  
Author(s):  
Charlie A. McClean ◽  
David Enrique Parra ◽  
Alexander Piven ◽  
Khalid Rahimov ◽  
Farid Hadiaman
Keyword(s):  
Caspian Sea ◽  
System Integration ◽  
The Caspian Sea ◽  
Integrated Sensor ◽  
Prefer Method ◽  
Coiled Tubing ◽  
Integration Test ◽  
Bottom Hole Assembly ◽  
System Focus ◽  
Lower Production

Abstract Over the past years the usage of coiled tubing as a prefer method to deploy long and heavy guns in highly deviated wells has been widely spread in the oil industry to provide a single run without killing the well, perforate in underbalance conditions, reduce risks and improve job efficiency. The three wells are located in the Caspian Sea. In two wells, the objective was to isolate lower intervals and perforate a new zone through tubing and casing between two packers. On the other well, the objective was to perforate a new interval through casing after running a new completion and isolate lower production zones. Due to the challenges involving gross length of the new intervals, guns size, well deviation and live deployment needs several techniques were evaluated. The best approach was to use an Advance Live-Well Deployment (ALWD) system to deploy and retrieve the guns with a tube wire-enabled Coiled Tubing Telemetry (CTT) system focus on both safety and cost saving compare with conventional wireline perforating. Extensive job planning involved coiled tubing (CT) simulations to reach target depths, shock loading modeling to ensure forces are within CT string limitations, system integration test to verify deployment/reverse technique procedure and system communication to electrically activate guns. CTT integrated sensor assembly was used during deployment/reverse operation with a tension, compression and torque (TCT) sub-assembly to monitor accurate upward/downward forces. In addition, CTT logging adapter assembly was used for depth correlation and electrical guns activation. The ALWD system; composed by connectors and deployment blow out preventor (BOP), prove to be an efficient way to run, perforate and retrieve gross intervals of 212 m, 246 m and 104 m with guns successfully. During all these jobs several lessons learnt were created in order to improve the deployment/reverse procedure for future jobs including not only operational steps but also deployment/reverse bottom-hole assembly (BHA) configurations. Based on the success of these case histories, the ALWD combined with CTT system has been proven to be the preferred method when dealing with long perforation intervals in life well conditions, thru-tubing environment.

Lessons Learned from the First Chemical Sand Consolidation in Zawtika Field

2021 ◽  
Author(s):  
Wiwat Wiwatanapataphee ◽  
Thanita Kiatrabile ◽  
Pipat Lilaprathuang ◽  
Noppanan Nopsiri ◽  
Panyawadee Kritsanamontri
Keyword(s):  
Control Method ◽  
Cost Effective ◽  
Lessons Learned ◽  
Candidate Selection ◽  
High Rate ◽  
Operation Performance ◽  
Coiled Tubing ◽  
Cost Effective Method ◽  
Sand Control ◽  
Gravel Pack

Abstract The conventional gravel pack sand control completion (High Rate Water Pack / Extension Pack) was the primary sand control method for PTTEPI, Myanmar Zawtika field since 2014 for more than 80 wells. Although the completion cost of gravel pack sand control was dramatically reduced around 75 percent due to the operation performance improvement along 5 years, the further cost reduction still mandatory to make the future development phase feasible. In order to tackle the well economy challenge, several alternative sand control completion designs were reviewed with the existing Zawtika subsurface information. The Chemical Sand Consolidation (CSC) or resin which is cost-effective method to control the sand production with injected chemicals is selected to be tested in 3 candidate wells. Therefore, the first trial campaign of CSC was performed with the Coiled Tubing Unit (CTU) in March to May 2019 with positive campaign results. The operation program and lesson learned were captured in this paper for future improvement in term of well candidate selection, operation planning and execution. The three monobore completion wells were treated with the CSC. The results positively showed that the higher sand-free rates can be achieved. The operation steps consist of 1) Perform sand cleanout to existing perforation interval or perforate the new formation interval. 2) Pumping pre-flush chemical to conditioning the formation to accept the resin 3) Pumping resin to coating on formation grain sand 4) Pumping the post-flush chemical to remove an excess resin from sand 5) Shut in the well to wait for resin curing before open back to production. However, throughout the campaign, there were several lessons learned, which will be required for future cost and time optimization. In operational view, the proper candidate selection shall avoid operational difficulties e.g. available rathole. As well, detailed operation plan and job design will result in effective CSC jobs. For instance, the coil tubing packer is suggested for better resin placement in the formation. Moreover, accommodation arrangement (either barge or additional vessel) and logistics management still have room for improvement. These 3 wells are the evidences of the successful applications in Zawtika field. With good planning, lesson learned and further optimization, this CSC method can be beneficial for existing monobore wells, which required sand control and also will be the alternative sand control method for upcoming development phases. This CSC will be able to increase project economic and also unlock the marginal reservoirs those will not justify the higher cost of conventional gravel pack.

scholarly journals Evaluasi Rigless Plug & Abandonment: Sebuah Studi Kasus

2020 ◽  
Vol 2 (2) ◽  
pp. 09-20
Author(s):  
Cindy Clara Afrisca ◽  
Keyword(s):  
Oil And Gas ◽  
Economic Value ◽  
Mineral Resources ◽  
Cost Effective ◽  
Daily Production ◽  
Coiled Tubing ◽  
Electric Line ◽  
Site Restoration ◽  
The Government ◽  
Operating Company

Oil was explored and found by Royal Dutch (Shell Group) geologist in early 1900. And since Indonesia’s independence, development in oil and gas projects was able to put Indonesia as one of major oil exporter country with daily production above 1 Million barrel per day in 1970 – 1990. With time as fields become mature, some of the fields have come to the end of its life cycle, where mostly 70% of Indonesia total old oil wells will have no economic value and has to be permanently Plug and Abandonment (P&A) as ruled by the government. It’s part of decommissioning an entire field with environmental preservation which called Abandonment and Site Restoration (ASR). As P&A will impact operating company investment as outlined in Ministry of Energy and Mineral Resources (ESDM) No. 15, 2008, efficient P&A operation should be evaluated to ensure proper planning and executions. The subject of evaluation is X well located onshore at Y Field, Java, Indonesia. P&A operation with multiple cements plugs as barriers to ensure no fluids migrations from one formation to others, or to surface. Evaluation between workover rig and rigless P&A operation with coiled tubing unit (CTU) and electric line (E-line) will be presented in this paper to value the expenditures and achieving the result as standardize by the government with accordance of operating company standard. Results show that rigless operation is the preferable solution, which lead to cost effective operation. Rigless operation saves 25% of P&A operations even tough with longer operation days.

scholarly journals Food Security, Environmental Health, and the Economy in Mexico: Lessons Learned with the COVID-19

2021 ◽  
Vol 13 (13) ◽  
pp. 7470
Author(s):  
Rebeca Monroy-Torres ◽  
Ángela Castillo-Chávez ◽  
Erika Carcaño-Valencia ◽  
Marco Hernández-Luna ◽  
Alex Caldera-Ortega ◽  
...  
Keyword(s):  
Food Security ◽  
Food Insecurity ◽  
Environmental Health ◽  
Public Policies ◽  
Cost Effective ◽  
Lessons Learned ◽  
Civil Society Organizations ◽  
Human Right ◽  
Healthy Environment ◽  
Mesh Terms

The COVID-19 pandemic showed an impact mainly on the health of people and the economy of households. The levels of food security in the world’s households, especially in Mexico, have decreased. When people do not have food security, their health is compromised and they have financial problems; on the other hand, environmental deterioration has a link with food security. The purpose of this review is to analysis of the current situation in Mexico of food security, environmental health and economy, the main lessons learned in these areas and their proposals integrating public policies. A review was carried out in the main databases (MEDLINE, Embase, CINAHL Plus, Web of Science, CAB Abstracts y PAIS Index) with the following keywords and according to the MeSH terms: Food security, food insecurity, environmental health, public policies, environmental, production, integrating the word COVID-19 in English and Spanish. Only 44.5% of Mexican households presented food security. For food insecurity, 22.6% had moderate and severe food insecurity, while 32.9% had mild insecurity. Food insecurity and the health impacts of environmental origin (waste management during the coronavirus pandemic, water contaminated by bacteria, viruses, and toxins; air pollution) generates impacts on economic activity by not offering food that meets health regulations. Without the application of cost-effective measures and interventions for the prevention and control of patients with obesity, the direct costs for 2023 will amount to 9 million dollars, which worsens the household economy. Despite having laws and policies on the right to food, a healthy environment (water), and opportunities for economic growth, these human rights are not fulfilled. The conclusion is that it is necessary to use a health and agroecological model to promote public policies (health, environment, and economy) that aims to prevent the discussed issues, with multidisciplinary and intersectoral interventions (government, academia, researchers, civil society organizations, industry, and population). This upholds the human right that all people should enjoy an adequate, healthy environment and have access to high-quality food.

Chemical Deliquification of Unconventional Gas Wells

2014 ◽  
Author(s):  
K.. Francis-LaCroix ◽  
D.. Seetaram
Keyword(s):  
Natural Gas ◽  
Best Practice ◽  
Oil And Gas ◽  
Large Deviation ◽  
Cost Effective ◽  
Gas Production ◽  
Lessons Learned ◽  
Offshore Platforms ◽  
Gas Wells ◽  
Current Production

Abstract Trinidad and Tobago offshore platforms have been producing oil and natural gas for over a century. Current production of over 1500 Bcf of natural gas per year (Administration, 2013) is due to extensive reserves in oil and gas. More than eighteen of these wells are high-producing wells, producing in excess of 150 MMcf per day. Due to their large production rates, these wells utilize unconventionally large tubulars 5- and 7-in. Furthermore, as is inherent with producing gas, there are many challenges with the production. One major challenge occurs when wells become liquid loaded. As gas wells age, they produce more liquids, namely brine and condensate. Depending on flow conditions, the produced liquids can accumulate and induce a hydrostatic head pressure that is too high to be overcome by the flowing gas rates. Applying surfactants that generate foam can facilitate the unloading of these wells and restore gas production. Although the foaming process is very cost effective, its application to high-producing gas wells in Trinidad has always been problematic for the following reasons: Some of these producers are horizontal wells, or wells with large deviation angles.They were completed without pre-installed capillary strings.They are completed with large tubing diameters (5.75 in., 7 in.). Recognizing that the above three factors posed challenges to successful foam applications, major emphasis and research was directed toward this endeavor to realize the buried revenue, i.e., the recovery of the well's potential to produce natural gas. This research can also lead to the application of learnings from the first success to develop treatment for additional wells, which translates to a revenue boost to the client and the Trinidad economy. Successful treatments can also be used as correlations to establish an industry best practice for the treatment of similarly completed wells. This paper will highlight the successes realized from the treatment of three wells. It will also highlight the anomalies encountered during the treatment process, as well as the lessons learned from this treatment.

Case Study- Real Time Downhole Telemetry CCL and Tension Compression, a Differentiator for Successful Manipulation of ICD's in Horizontal Wells

2021 ◽  
Author(s):  
Usman Ahmed ◽  
Zhiheng Zhang ◽  
Ruben Ortega Alfonzo
Keyword(s):  
Saudi Arabia ◽  
Real Time ◽  
Oil Recovery ◽  
Horizontal Wells ◽  
Differential Pressure ◽  
Successful Operation ◽  
Coiled Tubing ◽  
Electric Line ◽  
Wide Range ◽  
Ict System

Abstract Horizontal well completions are often equipped with Inflow Control Devices (ICDs) to optimize flow rates across the completion for the whole length of the interval and to increase the oil recovery. The ICD technology has become useful method of optimizing production from horizontal wells in a wide range of applications. It has proved to be beneficial in horizontal water injectors and steam assisted gravity drainage wells. Traditionally the challenges related to early gas or water breakthrough were dealt with complex and costly workover/intervention operations. ICD manipulation used to be done with down-hole tractor conveyed using an electric line (e-line) cable or by utilization of a conventional coiled tubing (CT) string. Wellbore profile, high doglegs, tubular ID, drag and buoyancy forces added limitations to the e-line interventions even with the use of tractor. Utilization of conventional CT string supplement the uncertainties during shifting operations by not having the assurance of accurate depth and forces applied downhole. A field in Saudi Arabia is completed with open-hole packer with ICD completion system. The excessive production from the wells resulted in increase of water cut, hence ICD's shifting was required. As operations become more complex due to fact that there was no mean to assure that ICD is shifted as needed, it was imperative to find ways to maximize both assurance and quality performance. In this particular case, several ICD manipulating jobs were conducted in the horizontal wells. A 2-7/8-in intelligent coiled tubing (ICT) system was used to optimize the well intervention performance by providing downhole real-time feedback. The indication for the correct ICD shifting was confirmed by Casing Collar Locator (CCL) and Tension & Compression signatures. This paper will present the ICT system consists of a customized bottom-hole assembly (BHA) that transmits Tension, compression, differential pressure, temperature and casing collar locator data instantaneously to the surface via a nonintrusive tube wire installed inside the coiled tubing. The main advantages of the ICT system in this operation were: monitoring the downhole force on the shifting tool while performing ICD manipulation, differential pressure, and accurately determining depth from the casing collar locator. Based on the known estimated optimum working ranges for ICD shifting and having access to real-time downhole data, the operator could decide that required force was transmitted to BHA. This bring about saving job time while finding sleeves, efficient open and close of ICD via applying required Weight on Bit (WOB) and even providing a mean to identify ICD that had debris accumulation. The experience acquired using this method in the successful operation in Saudi Arabia yielded recommendations for future similar operations.

Case History: Lessons learned From Retrieval of Coiled Tubing Stuck by Massive Hydrate Plug When Well Testing in an Ultra Deep Water Gas Well in Mexico

2011 ◽  
Author(s):  
Victor Gerardo Vallejo ◽  
Aciel Olivares ◽  
Pablo Crespo Hdez ◽  
Eduardo R. Roman ◽  
Claudio Rogerio Tigre Maia ◽  
...  
Keyword(s):  
Deep Water ◽  
Case History ◽  
Lessons Learned ◽  
Well Testing ◽  
Gas Well ◽  
Coiled Tubing ◽  
Hydrate Plug ◽  
Water Gas

scholarly journals A RECONNAISSANCE-SCALE GIS-BASED MULTICRITERIA DECISION ANALYSIS TO SUPPORT SUSTAINABLE BIOCHAR USE: POLAND AS A CASE STUDY

2017 ◽  
Vol 25 (2) ◽  
pp. 208-222 ◽  
Author(s):  
Agnieszka E LATAWIEC ◽  
Lewis PEAKE ◽  
Helen BAXTER ◽  
Gerard CORNELISSEN ◽  
Katarzyna GROTKIEWICZ ◽  
...  
Keyword(s):  
Agricultural Land ◽  
Multicriteria Analysis ◽  
Cost Effective ◽  
Lessons Learned ◽  
Research Papers ◽  
Potential Barriers ◽  
Indirect Land Use Change ◽  
Biomass Availability ◽  
Change Mitigation

Although increasing numbers of research papers regarding biochar are being published worldwide, in some countries growing interest in biochar has only recently been observed; this is true of Poland. We analysed information on biochar research in Poland alongside lessons learned elsewhere in order to identify the significant opportunities and risks associated with biochar use. This data fed into a GIS-based multicriteria analysis to identify areas where biochar application could deliver greatest benefit. We found that 21.8% of agricultural land in Poland has at least moderate indication for biochar use (soil organic matter below 2% and ph below 5.5), while 1.5% was categorized as a priority as it also exhibited contamination. Potential barriers identified included biomass availability and associated risks of indirect land-use change due to possible national and transnational biomass production displacement. Biochar use could have positive global consequences as a climate change mitigation strategy, particularly relevant in a country with limited alternatives. Scaling up a mitigation technology that is viable on account of its co-benefits might be cost-effective, which could, in turn, adjust national perspectives and stronger involvement in developing mitigation policies at the regional level. Biochar has much promise in temperate conditions and further research should therefore be assigned to explore biochar’s environmental and socio-economic impacts.

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