Enhancing Economics of Resources Development of Mature Mahakam Fields Through Innovation, Design Optimization, and Value Engineering

2021 ◽  
Author(s):  
Bhayu Widyoko ◽  
Patria Indrayana ◽  
Toto Hutabarat ◽  
Andriadi Budiarko ◽  
Mitterank Siboro ◽  
...  
Keyword(s):  
Water Depth ◽  
Gas Production ◽  
Value Engineering ◽  
Offshore Area ◽  
Energy Company ◽  
East Kalimantan ◽  
Production Sharing ◽  
Production History ◽  
Fit For Purpose ◽  
Gas Fields

Mahakam Contract Area is located in East Kalimantan Province, Indonesia. It covers an operating area of 3,266 km2, and consists of 7 producing fields. Most of Mahakam hydrocarbon accumulations are located below body of water, with wellhead production facilities installed in the estuary of Mahakam river (referred as swamp area, 0 to 5m water depth) and the western part of Makassar Strait (referred as offshore area, 30 to 70 m water depth). Mahakam production history goes as far back as mid 1970s with production of Handil and Bekapai oil fields. Gas production started by the decade of 1990s along with emergence of LNG trading, supplying Bontang LNG plant, through production of 2 giant gas fields: Tunu and Peciko, and smaller Tambora field. In the mid 2000s, Mahakam attained its peak gas production in the level of 2,600 MMscfd and was Indonesia's biggest gas producer. Two remaining gas discoveries, Sisi Nubi and South Mahakam, were put in production respectively in 2007 and 2012. Due to absence of new discoveries and new fields brought into production, Mahakam production has entered decline phase since 2010, and by end of 2020, after 46 years of production, the production is in the level of 600 MMscfd. In 2018, along with the expiration of Mahakam production sharing contract, Pertamina Hulu Mahakam (PHM), a subsidiary of Indonesian national energy company, Pertamina, was awarded operatorship of Mahakam Block. This paper describes the efforts undertaken by PHM to fight production decline and rejuvenate development portfolio, with focus on expanding subsurface development portfolio and reserves renewal by optimizing development concept and cost through fit-for-purpose design, innovation, and full cycle value engineering.

scholarly journals Technogenic risks of building and operation of oil and gas complexes in offshore area of the Caspian Sea

2019 ◽  
Vol 2019 (4) ◽  
pp. 46-59
Author(s):  
Николай Панасенко ◽  
Nikolay Panasenko ◽  
Алексей Синельщиков ◽  
Aleksey Sinel'schikov ◽  
Павел Яковлев ◽  
...  
Keyword(s):  
Caspian Sea ◽  
Oil And Gas ◽  
Gas Production ◽  
The Caspian Sea ◽  
Oil And Gas Production ◽  
Offshore Area ◽  
Oil And Gas Fields ◽  
Offshore Oil And Gas ◽  
Gas Fields ◽  
Offshore Oil

The article touches upon the problem of technogenic risks arising in the course of building and operating oil and gas complexes in the Caspian Sea taking into account the adoption of the Con-vention on the legal status of the Caspian Sea and regulation of the territorial division of the Caspian Sea. Technological risks are presented from the position of safety of industrial facilities in the offshore area and in the coastal zone, the impact of these facilities on the ecology of the Caspian is considered. The risk analysis was carried out taking into account world experience, as well as incidents that occurred at the offshore oil and gas production facilities in the Caspian Sea. There has been presented the layout of oil and gas fields at the bottom of the Caspian Sea and the division of the bottom based on adopting the Convention. A general description of the Caspian Sea has been given; unique features of the Caspian and the most unexplored seismic effects have been stated. It has been recommended to conduct a comprehensive assessment of the state of the seabed according to seismological, mud, volcanic and engineering-geological conditions; to develop measures for preventing and reducing the damage from hazardous natural processes and exploitation of oil and gas fields; to forecast the fluctuations of the Caspian Sea level, taking into account today’s economic activity; to study the natural and technogenic factors determining the environmental safety of the Caspian Sea; to monitor seismic phenomena, crustal movement in zones of tectonic faults at the sea bottom, etc. The speed and direction of wind currents in the Caspian Sea have been analyzed. The maps of mud volcanoes location in the Caspian basin (located on land, hidden and identified by seismic, geological, geophysical and geochemical methods, etc.) are illustrated. Conclusions are made about the high risks for developing hydrocarbon deposits in the Caspian Sea basin. There is the need to take into account environmental requirements and standards, to use modern technologies, to prevent incidents at offshore oil and gas production facilities.

scholarly journals UNLOCKING HIDDEN POTENTIAL OF SHALLOW RESERVOIR AT 1955-2342 mSS, IN RUHOUL FIELD

PETRO ◽  
2019 ◽  
Vol 8 (1) ◽  
pp. 1
Author(s):  
Abda Anwaratutthifal ◽  
Lestari Lestari ◽  
Reno Pratiwi
Keyword(s):  
High Energy ◽  
Gas Production ◽  
Drive Mechanism ◽  
Energy Company ◽  
Dynamic Synthesis ◽  
East Kalimantan ◽  
Straight Line ◽  
Shallow Zone ◽  
Well Correlation ◽  
Mahakam Delta

<p>As a human, live in the ever-changing environment, with the abundant amount of human movement, increasing population, and advancing technology, consumpting high energy is inevitable. Indonesia has been working to obtain better energy to fuel the world. As the multinational energy company, Pertamina Hulu Mahakam, located in East Kalimantan, operate world wide to extract oil and gas from the reservoir in Mahakam Delta, which already used high technology and qualified human resource to support the safe, efficient, and effective production process.</p><p>The petroleum system models, the contribution of marine shales to the generation of liquid and gaseous hydrocarbons in the Mahakam was considered negligible. The production of the oil fields has started quite early, however the major development phase of gas accumulation started within the last decade, with increasing activity since.</p><p>Ruhoul is an offshore gas field belongs to Pertamina Hulu Mahakam that located in Mahakam Delta, East Kalimantan, Indonesia. It covers an area of 350 km<sup>2</sup> and has a gross thickness of the payzone over 2000 m. Structural architecture of Ruhoul field is multilayered un-faulted anticline. Stratighraphycally, Ruhoul reservoirs are divided into two intervals which are Ruhoul Main Zone and Ruhoul Shallow. This study is only focused in Shallow zone area, they are Sh-8a, Sh-8c, and Sh-8d, as it is considered as remaining prospective area for Ruhoul field. For more specific, Sh-8a was produced by wells RJ-16A-M and RJ-2G-M.T3, Sh-8c was produced by well RJ-2G-M.T3, and Sh-8d was produced by well RJ-2G-M-T3.</p><p>Over time, the gas production in Ruhoul Field keep decreasing, therefore hidden gas production potential needs to be re-evaluated. The evaluation can be done by doing the dynamic synthesis analysis based on completion type used, production history, and well correlation.</p><p>The main objective of this study is to evaluate hydrocarbon potential in Ruhoul Shallow specific area. Several approaches will be used to assess Ruhoul Shallow zone prospect such an updated database, zone change inventory, and well correlation based on netpay map by layer with software Geolog 7.2.</p><p>Perform Dynamic Synthesis Analysis and P/Z Straight Line Material Balance Calculation are chosen as the methodology to assess the prospect zone of this field. The results of this process are candidates to be the re-opening zone, the value of GIIP, EUR, RR, RF, also the drive mechanism applied to each layer. Not only that, the results also obtained the Plateau rate stage curve in each layer.</p><p>The results showed two categories of re-opening candidates, P/Z methodology to calculate the value of GIIP and RF, and Plateau stage in each layer. Along with this study, the only well that suit to be the candidate for re-opening zone was only RJ-2G-M.T3 in Sh-8a, while the other layers and wells were not suit to be the candidate for re-opening zone. From the P/Z Straight Line calculation, the GIIP for the candidate (Sh-8a produced by RJ-2G-M.T3) is 1.15 BSCF, with 1.02 BSCF Gp max, and 89% RF, and has depletion drive as its drive mechanism. Based on Plateau stage with 4 MMSCFD as the plateau rate, the decline in RJ-2G-M.T3 (Sh-8a) started on July 2015.</p><p> </p>

Submarine Pipeline Installation JIP: Strength and Deformation Capacity of Pipes Passing Over the S-Lay Vessel Stinger

2006 ◽  
Author(s):  
Enrico Torselletti ◽  
Luigino Vitali ◽  
Erik Levold ◽  
Kim J. Mo̸rk
Keyword(s):  
Water Depth ◽  
Failure Modes ◽  
Bending Moment ◽  
External Pressure ◽  
Submarine Pipeline ◽  
Design Guideline ◽  
Moment Capacity ◽  
Sea Bottom ◽  
Major Vessel ◽  
Gas Fields

The development of deep water gas fields using trunklines to carry the gas to the markets is sometime limited by the feasibility/economics of the construction phase. In particular there is a market for using S-lay vessels in water depth larger than 1000m. The S-lay feasibility depends on the applicable tension at the tensioner which is a function of water depth, stinger length and stinger curvature (for given stinger length by its curvature). This means that, without major vessel up-grading and to avoid too long stingers that are prone to damages caused by environmental loads, the application of larger stinger curvatures than presently allowed by current regulations/state of the art is needed. The work presented in this paper is a result of the project “Development of a Design Guideline for Submarine Pipeline Installation” sponsored by STATOIL and HYDRO. The technical activities are performed in co-operation by DNV, STATOIL and SNAMPROGETTI. The scope of the project is to produce a LRFD (Load Resistant Factor Design) design guideline to be used in the definition and application of design criteria for the laying phase e.g. to S and J-lay methods/equipment. The guideline covers D/t from 15 to 45 and applied strains over the overbend in excess of 0.5%. This paper addresses the failure modes relevant for combined high curvatures/strains, axial, external pressure and local forces due to roller over the stinger of an S-lay vessel and to sea bottom contacts, particularly: • Residual pipe ovality after laying, • Maximum strain and bending moment capacity. Analytical equations are proposed in accordance with DNV OS F101 philosophy and design format.

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.

Interpretation of Permanent Well Monitoring Data to Improve Characterization of a Giant Oil Field

2021 ◽  
Author(s):  
Hans Christian Walker ◽  
Anton Shchipanov ◽  
Harald Selseng
Keyword(s):  
Reservoir Characterization ◽  
Time Lapse ◽  
Interference Analysis ◽  
Pressure Transient ◽  
Pressure Transients ◽  
Reservoir Simulations ◽  
Production History ◽  
Fault Leakage ◽  
Fit For Purpose

Abstract The Johan Sverdrup field located on the Norwegian Continental Shelf (NCS) started its production in October 2019. The field is considered as a pivotal development in the view of sustainable long-term production and developments on the NCS as well as creating jobs and revenue. The field is operated with advanced well and reservoir surveillance systems including Permanent Downhole Gauges (PDG), Multi-Phase Flow-Meters (MPFM) and seismic Permanent Reservoir Monitoring (PRM). This provides an exceptional basis for reservoir characterization and permanent monitoring. This study focuses on reservoir characterization to improve evaluations of sand permeability-thickness and fault transmissibility. Permanent monitoring of the reservoir with PDG / MPFM has provided an excellent basis for applying different methods of Pressure Transient Analysis (PTA) including analysis of well interference and time-lapse PTA. Interpretation of pressure transient data is today based on both analytical and numerical reservoir simulations (fit-for-purpose models). In this study, such models of the Johan Sverdrup reservoir regions have been assembled, using geological and PVT data, results of seismic interpretations and laboratory experiments. Uncertainties in these data were used to guide and frame the scope of the study. The interference analysis has confirmed communication between the wells located in the same and different reservoir regions, thus revealing hydraulic communication through faults. Sensitivities using segment reservoir simulations of the interference tests with different number of wells have shown the importance of including all the active wells, otherwise the interpretation may give biased results. The estimates for sand permeability-thickness as well as fault leakage obtained from the interference analysis were further applied in simulations of the production history using the fit-for-purpose reservoir models. The production history contains many pressure transients associated with both flowing and shut-in periods. Time-lapse PTA was focused on extraction and history matching of these pressure transients. The simulations have provided reasonable match of the production history and the time-lapse pressure transients including derivatives. This has confirmed the results of the interference analysis for permeability-thickness and fault leakage used as input for these simulations. Well interference is also the dominating factor driving the pressure transient responses. Drainage area around the wells is quickly established for groups of the wells analyzed due to the extreme permeability of the reservoir. It was possible to match many transient responses with segment models, however mismatch for some wells can be explained by the disregard of wells outside the segments, especially injectors. At the same time, it is a useful indication of communication between the regions. The study has improved reservoir characterization of the Johan Sverdrup field, also contributing to field implementation of combined PTA methods.

scholarly journals Gas transport at dense phase conditions for the development of deepwater fields in the Colombian Caribbean sea

2020 ◽  
Vol 10 (1) ◽  
pp. 17-32
Author(s):  
Manuel Cabarcas Simancas ◽  
Angélica María Rada Santiago ◽  
Brandon Humberto Vargas Vera
Keyword(s):  
High Pressures ◽  
Gas Transport ◽  
Cost Savings ◽  
Caribbean Sea ◽  
Gas Production ◽  
Dense Phase ◽  
Reservoir Properties ◽  
Hydraulic Simulation ◽  
Target Field ◽  
Gas Fields

The purpose of this article is to set out the benefits of using the dense phase gas transport in future projects in the Caribbean Sea and to verify that when operating pipelines at high pressures, more mass per unit of volume is transported, and liquid formation risks are mitigated in hostile environments and low temperatures.This study contains key data about gas production fields in deep and ultra-deep waters around the world, which serve as a basis for research and provide characteristics for each development to be contrasted with the subsea architecture proposed in this paper. Additionally, analogies are established between the target field (Gorgón-1, Kronos-1 and Purple Angel-1) and other offshore gas fields that have similar reservoir properties. Using geographic information systems, the layout of a gas pipeline and a subsea field architecture that starts in the new gas province is proposed.Finally, using a hydraulic simulation tool, the gas transport performance in dense phase is analyzed and compared with the conventional way of transporting gas by underwater pipelines, achieving up to 20 % in cost savings when dense phase is applied.

scholarly journals NATURAL AND ANTHROPOGENIC DYNAMICS OF PERMAFROST SOILS IN THE AREAS OF OIL AND GAS PRODUCTION IN YAMALO-NENETS AUTONOMOUS OKRUG

2015 ◽  
pp. 99-104 ◽  
Author(s):  
N. L. Mamaeva ◽  
S. A. Petrov
Keyword(s):  
Oil And Gas ◽  
Gas Production ◽  
Oil And Gas Production ◽  
Permafrost Rocks ◽  
Oil And Gas Fields ◽  
Permafrost Soils ◽  
Extreme North ◽  
Gas Fields ◽  
Cryogenic Processes ◽  
Nenets Autonomous

A research and comparison of natural and damaged (due to the active development of oil and gas fields) permafrost soils in the Jamalo-Nenets Autonomous Okrug were carried out. The analysis was run of correlation between an average monthly temperature of air, an average monthly sum of precipitation, the weight humidity and the thickness of the seasonal thawed layer. The conclusions were drawn about a poor resistance of landscapes on the permafrost rocks to the anthropogenic interventions, which in its turn is accompanied by the cryogenic processes and unfavorable influences on the Extreme North biosphere.

scholarly journals About this title - United Kingdom Oil and Gas Fields: 50th Anniversary Commemorative Volume

10.1144/m52 ◽  
2020 ◽  
Vol 52 (1) ◽  
pp. NP.1-NP
Keyword(s):  
Oil And Gas ◽  
50Th Anniversary ◽  
Reference Source ◽  
Geological Society ◽  
Oil And Gas Fields ◽  
Production History ◽  
Exploration And Production ◽  
History Of ◽  
The Uk ◽  
Gas Fields

Geological Society Memoir 52 records the extraordinary journey of more than 50 years that has led to the development of some 458 oil and gas fields on the UK Continental Shelf (UKCS). It contains papers on almost 150 onshore and offshore fields in all of the UK's main petroliferous basins. These papers range from look-backs on some of the first-developed gas fields in the Southern North Sea, to papers on fields that have only just been brought into production or may still remain undeveloped, and includes two candidate CO2 sequestration projects.These papers are intended to provide a consistent summary of the exploration, appraisal, development and production history of each field, leading to the current subsurface understanding which is described in greater detail. As such, the Memoir will be an enduring reference source for those exploring for, developing, producing hydrocarbons and sequestering CO2 on the UKCS in the coming decades. It encapsulates the petroleum industry's deep subsurface knowledge accrued over more than 50 years of exploration and production.

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