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 Indonesia Well Abandonment Standard Gap Analysis; A Review and Suggestion

2021 ◽  
Vol 10 (3) ◽  
pp. 115-124
Author(s):  
Ganesha R Darmawan
Keyword(s):  
Oil And Gas ◽  
Gap Analysis ◽  
Economic Value ◽  
Gas Wells ◽  
Environmental Preservation ◽  
Entire Field ◽  
Oil And Gas Wells ◽  
Site Restoration ◽  
The Government ◽  
Well Abandonment

The old oil and gas wells of approximately 70% are found to have no economic value in Indonesia, leading to being abandoned during the end of their lifecycle, as ruled by the government. This is part of decommissioning an entire field with an environmental preservation program, known as an Abandonment and Site Restoration (ASR). The program involves the evaluation of international permanent abandonment standards, as references for the designs, comparisons, and assessments of Indonesia’s policies. It also provides contrast gap analysis and suggestions in ensuring a proper permanent plug and abandonment approach, to avoid any future leaks or re-abandonment operations. Therefore, this study aims to determine and evaluate the gap analysis between Indonesia and International Well Abandonment Standards, as well as OGUK and NORSOK D-010. The results showed that abandonment activities had improvement opportunities philosophy, and practice, used for plugging/isolations, control lines, as well as reservoir and annular barriers. In addition, literature studies were performed to understand the abandonment philosophy for all reviewed standards, to provide proper suggestions or improvements.

What Hit and Miss in Indonesia CBM Project : Empirical Study Slowing Down Factors CBM Development and Propose Suitable Action for CBM Development in Indonesia by Using Analytical Hierarch Process.

2021 ◽  
Author(s):  
I.A. Firdaus
Keyword(s):  
Oil And Gas ◽  
Economic Value ◽  
Gas Production ◽  
Coal Bed ◽  
Production Sharing ◽  
High Investment ◽  
The Government ◽  
Exploration Period ◽  
Production Areas ◽  
Testing Standards

In 2008, the first Coal Bed Methane (CBM) PSC was signed in Indonesia. To date, 54 CBM PSCs have been awarded to explore and develop CBM Block in Indonesia. Twelve years later, only one PSC has submitted a Plan of Development but has not yet produced gas commercially. Most CBM PSCs have been struggling during the 10 years’ exploration period and some may receive extensions for 3 years under specific conditions. The lack of integrated authorities’ approval in the overlay of coal mining and natural gas production areas has become a great obstacle for CBM Development. Besides that, the government regulations in CBM activities have defects in PSC contract terms that may lead marginal economic value for contractors, especially due to high investment during the early development (C. Irawan, 2017). On the other hand, drilling regulations, Pipe Classing standards and Testing Standards following the Oil and Gas standards are too expensive for CBM Investment. According to our observations, CBM Regulations in Indonesia should be modified starting from the Exploration period, Production Sharing Contract Terms and Standard Operating Procedures to suit Indonesian CBM characteristics. Good coordination within government departments is a must for the success of CBM Exploration and Development.

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.

Production Tubing Leak Repair Using Reinforced Thermoplastic Pipe

2021 ◽  
Author(s):  
Olalere Sunday Oloruntobi ◽  
Prasanna Kumar Chandran ◽  
M Azuan Abu Bakar ◽  
Nurul Nazmin Zulkarnain ◽  
Hasrizal A Rahman ◽  
...  
Keyword(s):  
Oil And Gas ◽  
Cost Savings ◽  
Cost Effective ◽  
Internal Diameter ◽  
Hydrocarbon Recovery ◽  
Coiled Tubing ◽  
Well Integrity ◽  
Cost Effective Method ◽  
Integrity Management ◽  
Corrosive Environments

Abstract Operators are faced with never-ending well integrity issues relating to tubing leaks. This situation is particularly important in oil and gas wells that are producing in corrosive environments. When a well can no longer be safely produced due to well integrity issues relating to tubing leaks, an expensive workover is often performed to restore the tubing integrity. To improve the economics of a well intervention involving tubing leak repairs, a new cost-effective method is being proposed. The novel technology involves the installation of reinforced thermoplastic pipe (RTP) inside the existing tubing to isolate multiple leaks using a coiled tubing unit or an E-line. The RTP is engineered for downhole applications with custom designed connectors and accessories. It is designed to handle corrosive fluids (CO2 and H2S) and prevent downhole erosion caused by sand production. The RTP can be used to eliminate tubing – annulus communication in both producers and injectors with full compliance to well integrity management system. The results of the field trial in a gas injector well in Malaysia basin show that the RTP can provide a reliable means of restoring and enhancing the production of oil and gas with considerable cost savings (up to 80% cost reduction when compared to a conventional workover). In most cases, the high cost associated with a conventional workover can make it uneconomical when compared to the expected hydrocarbon recovery from the well, resulting in production deferment (well shut-in). The RTP can significantly increase the viability of repairing a larger percentage of the wells that are shut-in due to the loss of tubing integrity when the hydrocarbon recovery from the well is insufficient to justify a full workover. The significant cost savings provided by the RTP would dramatically improve economics and would likely result in more reserves recovered. The RTP also has a smoother surface that contributes to minimum friction and reduces the risk of scales formation when compared to the steel tubing of the same internal diameter.

South Africa "radical" plan to hit mining, oil and gas

2015 ◽  
Keyword(s):  
South Africa ◽  
Economic Policy ◽  
Affirmative Action ◽  
Oil And Gas ◽  
Mineral Resources ◽  
Minority Populations ◽  
Content Type ◽  
Court Action ◽  
The Government ◽  
Policy Shifts

Subject Economic policy shifts in South Africa. Significance Mineral Resources Minister Ngoako Ramatlhodi yesterday confirmed that the government is considering proposals that would enable it to set below-market "developmental" prices for certain minerals to boost downstream manufacturing. Together with "radical" plans to accelerate greater ownership by black individuals, it signals the rise of Left-leaning figures in the cabinet. Impacts State plans for an 853 million dollar hydrocarbons port at Saldanha Bay will only bear fruit if global prices, and local policies, improve. More frequent power blackouts will undermine industrialisation goals, despite government incentives to assist manufacturing. Affirmative action policies using national demographics in provinces with big minority populations will likely spur continued court action. Increases in black home buying (49.2% of buys in 2014; 43.0% in 2005) is likely to continue, though more slowly given income stagnation.

Onshore Site Restoration; Overview and Lesson Learned

2021 ◽  
Author(s):  
G. P. Atmaja
Keyword(s):  
Oil And Gas ◽  
Mineral Resources ◽  
Treatment Method ◽  
Environmental Risks ◽  
Lessons Learned ◽  
Production Operation ◽  
Site Restoration ◽  
Contract Expiration ◽  
Ministerial Decree ◽  
Step Site

Ministerial Regulation of Energy and Mineral Resources (PerMen ESDM) No. 15/2018 and PTK-040 (PTK–040 /SKKMA0000/2018/S0) rev-1, which serve as the recent abandonment and site restoration (ASR) legal basis, mandated Oil and Gas upstream activity to perform EBA (Environmental Based Assessment) prior to or at the contract expiration date, or end-of-contract (EOC). The result of EBA which leads to ASR planning and activities, includes well plug & abandonment (P&A), facility decommissioning, and site restoration activities. The purpose of site restoration is to eliminate environmental risks by performing clean-up of the identified impacted sites from upstream exploitation and production operation activities. Onshore site restoration activities, as part of ASR, refers to several technical regulatory references. They include Ministerial Regulation of Environment (PerMenLH) No. 33/2009 concerning step-by-step Site Restoration Activity (site clearing, delineation, excavation, sampling, segregation, treatment), Governmental Regulation (PP) No. 101/2014 Attachment V. concerning reference of target analyte parameter and criteria, and Ministerial Decree of Environment (KepMenLH) No. 128/2003 on treatment method. This paper intends to provide information, which include overview, and lessons learned from onshore site restoration, as part of ASR activities, to stakeholders who may be subject to ASR implementation.

scholarly journals The Use of Big Data in The Oil and Gas Upstream Industry

2019 ◽  
Vol 2 (1) ◽  
pp. 14-28
Author(s):  
Khalid Istiqlal Syaifullah
Keyword(s):  
Big Data ◽  
Cyber Security ◽  
Data Analytics ◽  
Oil And Gas ◽  
Open Data ◽  
Big Data Analytics ◽  
Mineral Resources ◽  
Physical Models ◽  
Exploration And Production ◽  
The Government

A study has been done to perceive the uptake and impact of Big Data in the exploration and production of oil and gas in Indonesia compared to Norway. Interviews were conducted to officials in the Ministry of Energy and Mineral Resources (MoEMR) and the state regulator, SKK Migas. In both industries, more data is being generated more than ever in exploration, production, drilling, and operations, indicating potential application of Big Data. However, approach towards data has remained classical with physical models in opposed to common Big Data approach, which is data-driven analytics. Several impacts of Big Data in both industries are highlighted, including new demand for data analysts, the need for regulations surrounding cyber-security, improvement of safety and environment (which hasn’t been considered in Indonesia), and growing need for more trust and regulations towards open data. Open data in the two industries has seen two different trajectories with Indonesia only implementing it very recently, while the NCS has seen open data drives competition since 1999. This study produced recommendations for the government of Indonesia on open data and how uptake and application of Big Data analytics in EOR could potentially increase national petroleum production to desired levels. Keywords: Big Data, open data, oil and gas in Indonesia, Norway Continental Shelf, data analytics, EOR

What Does Rent Give to Federal Budget (on the Russia's Budget Dependence upon "Oil Dollars")

2004 ◽  
pp. 51-69 ◽  
Author(s):  
E. Sharipova ◽  
I. Tcherkashin
Keyword(s):  
Oil And Gas ◽  
Strong Dependence ◽  
Oil Prices ◽  
Federal Budget ◽  
Oil And Gas Industry ◽  
Gas Industry ◽  
Resource Rent ◽  
Tax Legislation ◽  
Russian Economy ◽  
The Government

Federal tax revenues from the main sectors of the Russian economy after the 1998 crisis are examined in the article. Authors present the structure of revenues from these sectors by main taxes for 1999-2003 and prospects for 2004. Emphasis is given to an increasing dependence of budget on revenues from oil and gas industries. The share of proceeds from these sectors has reached 1/3 of total federal revenues. To explain this fact world oil prices dynamics and changes in tax legislation in Russia are considered. Empirical results show strong dependence of budget revenues on oil prices. The analysis of changes in tax legislation in oil and gas industry shows that the government has managed to redistribute resource rent in favor of the state.

Financial and Economic Support of Innovation Processes in the Russian Fuel and Energy Complex

2019 ◽  
Vol 12 (3) ◽  
pp. 77-85
Author(s):  
L. D. Kapranova ◽  
T. V. Pogodina
Keyword(s):  
Oil Recovery ◽  
Large Scale ◽  
Oil And Gas ◽  
New Technologies ◽  
Innovative Development ◽  
Oil Reserves ◽  
Energy Complex ◽  
Innovation Activities ◽  
Substantial Investment ◽  
The Government

The subject of the research is the current state of the fuel and energy complex (FEC) that ensures generation of a significant part of the budget and the innovative development of the economy.The purpose of the research was to establish priority directions for the development of the FEC sectors based on a comprehensive analysis of their innovative and investment activities. The dynamics of investment in the fuel and energy sector are considered. It is noted that large-scale modernization of the fuel and energy complex requires substantial investment and support from the government. The results of the government programs of corporate innovative development are analyzed. The results of the research identified innovative development priorities in the power, oil, gas and coal sectors of the fuel and energy complex. The most promising areas of innovative development in the oil and gas sector are the technologies of enhanced oil recovery; the development of hard-to-recover oil reserves; the production of liquefied natural gas and its transportation. In the power sector, the prospective areas are activities aimed at improving the performance reliability of the national energy systems and the introduction of digital technologies. Based on the research findings, it is concluded that the innovation activities in the fuel and energy complex primarily include the development of new technologies, modernization of the FEC technical base; adoption of state-of-the-art methods of coal mining and oil recovery; creating favorable economic conditions for industrial extraction of hard-to-recover reserves; transition to carbon-free fuel sources and energy carriers that can reduce energy consumption and cost as well as reducing the negative FEC impact on the environment.

Sand Free Production Success Through Proven Technology Enabler from An Untapped Heterogeneous Reservoir Zone Utilizing Gravel Pack Replacement Methodology

2020 ◽  
Author(s):  
Y. Anggoro
Keyword(s):  
Oil And Gas ◽  
Erosion Resistance ◽  
Cost Effective ◽  
High Rate ◽  
Screen Design ◽  
Sand Control ◽  
Rules Of Thumb ◽  
Production Success ◽  
Control Technologies ◽  
Gravel Pack

The Belida field is an offshore field located in Block B of Indonesia’s South Natuna Sea. This field was discovered in 1989. Both oil and gas bearing reservoirs are present in the Belida field in the Miocene Arang, Udang and Intra Barat Formations. Within the middle Arang Formation, there are three gas pay zones informally referred to as Beta, Gamma and Delta. These sand zones are thin pay zones which need to be carefully planned and economically exploited. Due to the nature of the reservoir, sand production is a challenge and requires downhole sand control. A key challenge for sand control equipment in this application is erosion resistance without inhibiting productivity as high gas rates and associated high flow velocity is expected from the zones, which is known to have caused sand control failure. To help achieve a cost-effective and easily planned deployment solution to produce hydrocarbons, a rigless deployment is the preferred method to deploy downhole sand control. PSD analysis from the reservoir zone suggested from ‘Industry Rules of Thumb’ a conventional gravel pack deployment as a means of downhole sand control. However, based on review of newer globally proven sand control technologies since adoption of these ‘Industry Rules of Thumb’, a cost-effective solution could be considered and implemented utilizing Ceramic Sand Screen technology. This paper will discuss the successful application at Block B, Natuna Sea using Ceramic Sand Screens as a rigless intervention solution addressing the erosion / hot spotting challenges in these high rate production zones. The erosion resistance of the Ceramic Sand Screen design allows a deployment methodology directly adjacent to the perforated interval to resist against premature loss of sand control. The robust ceramic screen design gave the flexibility required to develop a cost-effective lower completion deployment methodology both from a challenging make up in the well due to a restrictive lubricator length to the tractor conveyancing in the well to land out at the desired set depth covering the producing zone. The paper will overview the success of multi-service and product supply co-operation adopting technology enablers to challenge ‘Industry Rules of Thumb’ replaced by rigless reasoning as a standard well intervention downhole sand control solution where Medco E&P Natuna Ltd. (Medco E&P) faces sand control challenges in their high deviation, sidetracked well stock. The paper draws final attention to the hydrocarbon performance gain resulting due to the ability for choke free production to allow drawing down the well at higher rates than initially expected from this zone.

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