A Successful Attempt to Insert Coiled Tubing Through Parted Production Tubing with a Malfunctioned Downhole Safety Valve to Perform Extralightweight Cement Treatment to Regain Pressure Integrity for Plug and Abandonment

2016 ◽  
Author(s):  
Jae Seok Yi ◽  
Jong Yong Lee ◽  
Hyun Jung Oh ◽  
Tan Khoa Nguyen ◽  
Tran Thang Nguyen ◽  
...  
Keyword(s):  
Safety Valve ◽  
Coiled Tubing ◽  
Successful Attempt ◽  
Production Tubing ◽  
Cement Treatment

Successful Remediation of Sustained Casing Pressures in Gas Cap Injector Wells with the Use of Flexible and Self Healing System

2021 ◽  
Author(s):  
Bipin Jain ◽  
Abhijeet Tambe ◽  
Dylan Waugh ◽  
Moises MunozRivera ◽  
Rianne Campbell
Keyword(s):  
Self Healing ◽  
Injection Wells ◽  
Coiled Tubing ◽  
Cement System ◽  
Sustained Casing Pressure ◽  
Casing Pressure ◽  
New Generation ◽  
Prudhoe Bay ◽  
Production Tubing

Abstract Several injection wells in Prudhoe Bay, Alaska exhibit sustained casing pressure (SCP) between the production tubing and the inner casing. The diagnostics on these wells have shown communication due to issues with casing leaks. Conventional cement systems have historically been used in coiled-tubing-delivered squeeze jobs to repair the leaks. However, even when these squeeze jobs are executed successfully, there is no guarantee in the short or long term that the annular communication is repaired. Many of these injector wells develop SCP in the range of 300-400 psi post-repair. It has been observed that the SCP development can reoccur immediately after annulus communication repair, or months to years after an injector well is put back on injection. Once SCP is developed the well cannot be operated further. A new generation of cement system was used to overcome the remedial challenge presented in these injector wells. This document provides the successful application of a specialized adaptive cement system conveyed to the problematic zone with the advantage of using coiled tubing equipment for optimum delivery of the remedial treatment.

Customized Solutions for Coiled Tubing Interventions in the Bolivian Sub-Andean Basin

2021 ◽  
Vol 73 (06) ◽  
pp. 44-45
Author(s):  
Chris Carpenter
Keyword(s):  
High Pressure ◽  
Acid Treatment ◽  
Abu Dhabi ◽  
Test Results ◽  
High Confidence ◽  
Coiled Tubing ◽  
High Pressure High Temperature ◽  
National Production ◽  
Acid Wash ◽  
Production Tubing

This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper SPE 202620, “A Review of 25 Coiled Tubing Well Interventions: Customized Solutions for Bolivian Sub-Andean Basin,” by Jovanny A. Hernandez, SPE, Luis F. Antelo, SPE, and Carlos D. Rodriguez, Halliburton, et al., prepared for the 2020 Abu Dhabi International Petroleum Exhibition and Conference, Abu Dhabi, held virtually 9–12 November. The paper has not been peer reviewed. Fields in the Bolivian Sub-Andean Basin are remote and difficult to access. The producing zones include the country’s most challenging wells, with depths of up to 26,000 ft, with high pressure/high temperature (HP/HT), high gas cut, crossflow, dogleg severity, and well-access restrictions. The complete paper reviews 25 coiled tubing rigless well interventions (CTRWI) to extend the life of those wells, including operations involving nitrogen (N2) lift, acid wash, milling, shifting sleeves, setting packers, stimulation, velocity strings (VS), and fishing. Introduction CTRWI in Sub-Andean Basin fields had not been implemented historically because of limited road access to the fields, lack of available equipment with high technical capabilities, high pressure, and well depth. Beginning in 2017, however, operators evaluated the risk and elected to perform CTRWI involving stimulation, cleanout, N2 lift, fishing, VS jobs, and other techniques. Equipment with specialized capabilities was requested to address the operational requirements and the ability to travel on the remote roads while respecting transit regulations limiting maximum weight to 55 tons. The challenges to transporting equipment economically include - Transportation of large reels of 2⅞-in. coiled tubing (CT) string to complete dual-sectioned VS installations - Transportation of CT unit with 6,600 m of 1¾-in. CT string (weight of less than 55 tons) - Continuously moving large volumes of N2 to the field Wells in these fields were drilled no more than 10 years ago. The majority were built with smart completions, several production layers separated with swell packers and flowing through sliding sleeves configured with the same direction of actuation for opening and closure. Completions are configured with production tubing sizes of 7, 5, 4½, and 3 in. The tubing and accessories are made from chrome 13 because of the presence of carbon dioxide in the production fluids. The region includes some exploratory fields having HP/HT conditions and mature fields with declining production. These wells are important for both the operators and the local government because their production represents more than 50% of national production. On-Site Laboratory Testing Characteristics of produced formation water and mineralogy tests of water samples helped identify a calcium carbonate (CaCO3) scale type. Because CaCO3 scale is known to be acid-soluble, a tailored acid-treatment system was selected with a static formation temperature between 220 to 286°F. On-site laboratory tests using a combination of 13% acetic and 9% formic retarded acid treatment systems were applied to the samples obtained, and results of a solubility test were observed. The selected treatment was demonstrated to be highly effective at dissolving CaCO3 scale according to the test made at the wellsite. High confidence was placed in the test results of the acid-treatment sample because dissolution was above 85% in a 4-hour test period under static well temperature.

Coiled-Tubing Milling of an Incoloy Alloy 925 Safety Valve Flapper in the North Sea

2007 ◽  
Author(s):  
Rodney Alan Farquhar ◽  
Frank Rattray ◽  
Alex Annandale ◽  
Alan Reid ◽  
Steve Glegg
Keyword(s):  
North Sea ◽  
Safety Valve ◽  
Coiled Tubing ◽  
The North ◽  
The North Sea ◽  
Incoloy Alloy

THE COBIA 2 SUBSEA COMPLETION

1984 ◽  
Vol 24 (1) ◽  
pp. 153
Author(s):  
M. N. Shaw
Keyword(s):  
Crude Oil ◽  
Safety Valve ◽  
Effective Means ◽  
Cost Effective ◽  
The Novel ◽  
Successful Operation ◽  
Field Development ◽  
Coiled Tubing ◽  
The World ◽  
Marginal Field

Subsea completions are recognised worldwide as a cost effective means of developing marginal reservoirs, accelerating production and draining reservoir extremities which cannot be reached from conventional platforms. To date, more than 280 subsea completions have been installed around the world. Cobia 2, the first subsea completion in Australian waters, commenced production in Bass Strait in June 1979. It continued to produce until April 1983, when it was shut-in following the commencement of production from the Cobia platform. In its four years of operation, the well produced over 280 megalitres (1.78 million barrels) of crude oil, with peak well rates reaching as high as 750 kilolitres per day in the latter stages of its producing life. Overall, Cobia 2 has been a technical and commercial success.The need for regular pumpdown or TFL ('through flowlines') wax-cutting operations in the flowlines to maintain high levels of production generated a great deal of confidence in the use of TFL techniques for routine and non-standard subsea well servicing. In an industry 'first', TFL methods were developed to lock open and seal a leaking subsurface safety valve and, within it, set a special insert subsurface safety valve. This work allowed the well to be returned to production in a situation where a conventional workover of the well was not feasible.Other well-servicing techniques developed during the Cobia 2 project involved the novel use of a coiled tubing unit to retrieve TFL tools which had become stuck in the flowlines during the wax-cutting operations.The highly successful operation of Cobia 2 has proved the viability of this type of completion for marginal field development in Australia.

Coiled Tubing as Initial Production Tubing: An Overview of Case Histories

1995 ◽  
Vol 47 (05) ◽  
pp. 409-413
Author(s):  
H.L. Nirider ◽  
P.M. Snider ◽  
K.D. Walsh ◽  
J.R. Cordera ◽  
Joe Williams
Keyword(s):  
Case Histories ◽  
Coiled Tubing ◽  
Production Tubing

Limits on the Penetration of Coiled Tubing in Horizontal Oil Wells: Effect of the Pipe Geometry

2005 ◽  
Vol 219 (11) ◽  
pp. 1191-1197 ◽  
Author(s):  
I McCourt ◽  
J Kubie
Keyword(s):  
Economic Benefits ◽  
Oil Wells ◽  
External Diameter ◽  
Friction Forces ◽  
Coiled Tubing ◽  
Tubing String ◽  
Maximum Penetration ◽  
Pipe Geometry ◽  
Remedial Work ◽  
Production Tubing

To carry out remedial work in oil wells through the production tubing string, a method using a continuous length of steel coiled tubing is used. In horizontal wells substantial friction forces are generated which resist the motion of the tubing as it is pushed into the well. As the penetration increases, the friction forces arising from the contact of the tubing with the inner casing wall increase too, and the tubing buckles. The buckling is initially sinusoidal but eventually transforms into helical. At this point the force required to push the tubing rises dramatically, and the maximum penetration is then rapidly reached. Considerable economic benefits could be gained if the limits on the maximum penetration of coiled tubing in horizontal oil wells could be increased. This article discusses ways of increasing the penetration of coiled tubing in horizontal oil wells by managing the geometry of the coiled tubing. It is shown that the best strategy is to keep the external diameter of the coiled tubing constant, and to make up the coiled tubing from several sections, each with uniform, but increased wall thickness. It is shown that with two sections the maximum penetration can be increased by about half, and that with three sections the maximum penetration can be increased by about two-thirds.

Coiled Tubing as Initial Production Tubing: An Overview of Case Histories

1994 ◽  
Author(s):  
H. L. Nirider ◽  
P. M. Snider ◽  
K. D. Walsh ◽  
J. R. Cordera ◽  
Joe Williams
Keyword(s):  
Case Histories ◽  
Coiled Tubing ◽  
Production Tubing

First Time Worldwide Application of Glass Reinforced Epoxy Lined Tubing for Prevention of Asphaltene Deposition on Tubing in Oil Wells – A Case Study from Kuwait

2021 ◽  
Author(s):  
Reji Edappillikulangara Chinnappan ◽  
Milan Telang ◽  
Riyad Quttainah ◽  
Gokulnath Radhakrishnan ◽  
Alwyn Fernandes ◽  
...  
Keyword(s):  
Oil Wells ◽  
Mitigation Strategies ◽  
Metallic Surfaces ◽  
Clear Cut ◽  
Coiled Tubing ◽  
Asphaltene Deposition ◽  
Before And After ◽  
Implementation Costs ◽  
Operational Issues ◽  
Production Tubing

Abstract Asphaltene deposition in production tubing is a major flow assurance challenge. Common strategies to mitigate Asphaltene deposition downhole include mechanical or solvent cleanouts and chemical inhibition. These are associated with production deferment, high job costs, HSE risks and operational issues. In a worldwide first, Kuwait Oil Company (KOC) has addressed this challenge using Fiberglass (GRE) Lined Production Tubing. This technology was implemented in two trial wells. This paper chronicles the different mitigation strategies employed by KOC and presents the findings of the above-mentioned successful trials. Tendency of scale to stick on smoother, non-metallic surfaces, is known to be less than on bare steel surface. KOC had trialed internal coating to mitigate Asphaltene deposition in tubing, but the experience was not satisfactory. KOC has been successfully using GRE lined tubing for corrosion protection and scale prevention in oil and water wells. Considering GRE's smoother surface, lower zeta energy and thermal insulation, it was decided to conduct a trial of GRE lined tubing in wells with Asphaltene deposition problems. Frequency of cleanout and Well Head Pressure (WHP) trends, before and after installation of GRE Lined Tubing, were compared for evaluation. The paper chronicles the trial results and provides a comparison of implementation costs against currently employed tubing cleanouts by Coiled Tubing (CT) using a Diesel-Toluene mixture. Two wells, requiring frequent tubing cleanout of Asphaltene, were selected as candidates. Trends over a period of 13-15 months after installation of GRE lined tubing showed up to 74 % reduction in WHP decline rate compared to pre-installation periods. Cleanouts were avoided against an earlier frequency of 3 to 3.5 jobs per year. This resulted in following benefits: (1) Direct annual operational savings of 519,750 US $ per well (2) Additional production by increased uptime of 1 to 1 ½ months (3) Avoidance of Coiled Tubing sticking, occurring in similar wells, and the resultant workover cost (4) Eliminating production deferment due to this workover (5) An environment friendly and safe methodology not requiring handling of toxic, highly flammable Toluene, used for the clean outs. Comparison of the economics show clear-cut benefits of GRE lined tubing over tubing cleanouts. In view of the applicability in most of their high API gravity Jurassic oil wells, KOC has decided on wide scale implementation of this technology. As this is the first known case of its kind worldwide, we expect that this paper will be highly beneficial to operators faced with challenges in producing Asphalteinic oil and those engaged in CO2 EOR campaigns. Besides sharing experience, the authors aim to generate global operator engagement to optimize this new solution, possibly combined with other solutions, to tackle Asphaltene deposition as efficiently as possible.

Innovative Remediation Techniques for Restoring Well Integrity with Coil Tubing Patch

2021 ◽  
Author(s):  
Ho Yin Yap ◽  
Leong Hing Chua ◽  
Fidelis Sipangkui Brian Rayner ◽  
Peng Yoke Low ◽  
Bato Connie
Keyword(s):  
Single Point ◽  
Metal Loss ◽  
Maximum Deviation ◽  
Coiled Tubing ◽  
High Penetration ◽  
East Malaysia ◽  
System Technique ◽  
Single String ◽  
Cooperative Project ◽  
Production Tubing

Abstract Well BO-X is located in offshore East Malaysia and was completed as a single string producer on 22nd July 2014. Well BO-X has maximum deviation of 57.5 deg at depth 3,150ft MDTHF. Based on the MIT logs, several leaks have been detected on the string which caused the well unable to flow. Well was flowing for 2 years before identified with multiple leaks due to severe metal loss and high penetration along more than 1,400 ft tubing interval (400 ft above the TRSCSSV and 1000ft below the TRSCSSV). Multiple attempts tried to flow well but failed due to circulation of gas through leak points at tubing. Tubing was found to be leaking at multiple points above TRSCSSV (449 ft MDTHF) with severe pitting / penetration at a single point below between ESP discharge head and TRSCSSV from 2 MIT runs. The leaks were detected at depth (1) 64 ft MDTHF, (2) 126.8 ft MDTHF and (3) 221.2 ft MDTHF. There were also several potential leaks detected along the long string above the top packer Reservoir simulation studies and production rate both indicated that the production tubing leaks is deteriorate and few methods were considered to bring back the optimum production. Tubing pack off system technique was considered as it can deploy with slickline, retrievable and ideal use to isolate tubing leaks however there is potential that more leaks will develop along the production years. Workover as an option to replace the tubing could easily cost millions of dollar (USD) Before surrender the well to workover team, a coiled tubing patch system was designed in a cooperative project involving operator and service company to provide an improved tubing pack off system which can straddle the tubing leaks by using coiled tubing instead of spacer pipe. This coiled tubing patch system was significantly lower cost and keep the functionality of Tubing Retrievable Surface Control Subsurface Safety Valve (TRSCSSV) by installing two straddle packer system – upper straddle packer system to cover leak points above TRSCSSV while another straddle system to cover leak points below TRSCSSV (Fig 1).

State-of-the-Art Coiled Tubing Technology at Prudhoe Bay, Alaska

2007 ◽  
Author(s):  
Jennifer Yvonne Julian ◽  
Kirk Charles Forcade ◽  
Taylor L. West ◽  
Kevin yeager ◽  
Robert Lee Mielke ◽  
...  
Keyword(s):  
State Of The Art ◽  
Coiled Tubing ◽  
Prudhoe Bay
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