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Engineer Drilling

Bokn, Rogaland County Municipality, Norway
December 04, 2019

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Bryne, Norway

+479******* (Mobile)


about/ (Other)


sigve-hamilton- (Personal)

Top Skills


Petroleum Engineering



English (Native or Bilingual)

Norwegian (Native or Bilingual)

German (Professional Working)

Sigve Hamilton Aspelund

Senior drilling engineer

Bryne, Rogaland, Norway


Adaptation accomplished realist, outstanding organizational skills and business sense, desire to achieve concrete results toward perfectionism, prefer hard work, ultimate realist, possess practical properties combined with highly developed intelligence, sees quickly new opportunities and use this to his own benefit, hard working, fair, very independent, convinced that morality is more important than anything else, resourceful, action-oriented person, eager to expand own knowledge, expect to reach targets, responsible, industrious, resolute and energetic, natural leader and has a natural talent as a presenter


Sigve Hamilton Aspelund

Senior Drilling Engineer

January 2017 - Present

Senior drilling engineer at ACL engineering

Business agent Crimson oil tools: Searching for projects within


- Risk

- Petroleum engineering: Reservoir, production & drilling. Subsea & Subsurface

- Geopolitics & oil and gas management

- Ph.D.

- Finance advisor

- Geology

- Quantum physics

- Electronics

- Veapons industry

Sales, marketing and business development

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Aspelund Consulting Energy Offshore Development International & National

Petroleum engineer consultant (Entrepreneur)

August 2009 - October 2018 (9 years 3 months)


Offshore structure design & Inspection & Maintenance of Subsea Pipelines Location: Kuala Lumpur, Malaysia Client: Mellitha Oil & Gas Rig inspection course. Location: Kuala Lumpur, Malaysia Client: CCED Global geo political Oil & gas management & Distribution course. Client: KAZGUU Business school, Astana Kazakhstan

Developed an Exploration and Production course

07.2014-09.2014: Petroleum engineering team leader: Oil Plus. Newbury. England:

Business development proposal: Reservoir simulation: H2S analysis with CMG

(Geochemistry/ HSE)

Senior production engineer: Digital oilfield planning. Client: BP. Dubai. Advisor: Well Intervention Services. Client: Coleman research Course director: Managed pressure-drilling systems. Multilateral wells. Coiled tubing underbalanced drilling. Client: JSC Ontustik Munaigaz, Neftserviceholding LTD, OJSC Surgutneftegas, Gazprom Mining Orenburg Ltd, BelNIPIneft “Belorusneft”. Stavanger

Course director: Petroleum drilling fundamentals (Well control). Client: CNOOC. Aberdeen.

11.2012 – 03.2013: Project risk advisor & engineer. Client: FMC Technologies. Projects: CLOV, GIRRI & Edradour (Total Angola and UK). Kongsberg Chairman: Doing more with drilling data. Client: Finding petroleum. Stavanger Course director: Reservoir modelling and characterization. Client: NNPC. London

03-04.2012:Resource coordinator: RCC. Stavanger

Course director: Introduction to oil & gas industry. Client: KPOC. Kuala Lumpur, Malaysia

Presentation: Offshore safety related to computer interfaces and information. People and the digital oilfield Client: Finding petroleum. Stavanger Offshore security and HSE. Bringing businesses from east and west together. Client: TransEuropean Centre. Stavanger

08.2010-11.2010: Teacher: Akademiet. Stavanger and Sandnes 08.2009-11.2009: Teacher: S.O.T.S.

2009-2012: Advisor: Client: GLG (New York)


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Inspector and study leader

March 2016 - August 2016 (6 months)

Courses held:

Petroleum geology in Trondheim

Drilling technology and casing in Bergen and Ålesund Hydraulic and pneumatic in Bergen and Trondheim

Production technology in Ålesund

Reference: Thore Bergsaker

Oil Plus Ltd

Petroleum engineering team leader

July 2014 - September 2014 (3 months)

Newbury, United Kingdom

Business development proposal: Reservoir simulation: H2S analysis with CMG STAR (Geochemistry/ HSE)

FMC via IDEA Consultants via Aspelund Consulting Energy Offshore Development International National

Project risk advisor

November 2012 - March 2013 (5 months)


Risk engineer in the pre-engineering FMC organization with projects outside Angola and Shetland

Risk advisor at the Subsea field developments CLOV: Cravo, Lirio, Orquidea and Violeta discoveries and GIRRI: Rosa and Girassol fields operated by Total


The essential purpose of risk management in projects and tenders are to improve project and tender performance via the systematic and iterative process designed to identify, analyze, evaluate, and treat project related risk elements. Risk elements are compiled, recorded and managed throughout the tender period and project life cycle.

• Establishment of project risk management plan in accordance to company project risk management process

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• Establishment and maintenance of a risk register based on risk analysis done in tender phase (if available), lessons learned and project risk assessment methodology

• Ensuring that projects work according to company global risk management process for projects

• Facilitate risk meetings and co-ordinate risk responses

• Monitor and control that the risk strategies are implemented in a timely manner

• Coordinate and participate in risk evaluation, development of mitigation plans, monitor, summarize and report risk status

• Compile record and follow up risks out of tolerance level in the risk register

• Create a project risk management close out report

• Support projects or tenders with risk analysis (quantification and /or bowtie) upon request

• Report updates and improvements for process, methodology and tools as a result of feedback from the organization and / or changes in external conditions, to the local process owner

• Provide input to internal and external monthly reporting. Internal risk status reporting consisting of aggregated risk status from projects, project portfolio and/ or tender work

Via IDEA Consultants

Reference: Jarle Weseth



2009 - 2012 (4 years)

Greater New York City Area

Offshore Drilling Rigs: Management, Operations, and environment: Client : Gehrson Lehrman Group

o Safety cultures

o Employee training

o Engineering and innovation capabilities

o Management and strategic positions

o Corporate cultures

o Key operational benchmarks

Drilling (Alaska) Client : Maven

Natural gas compression (Canada) Client : Maven

European oil production industry Client : Gehrson Lehrman Group Page 4 of 23

Norwegian drilling waste management market Client : Gehrson Lehrman Group

Norwegian oil industry service – Client : Gerson Lehrman Group Ocean Rig

Quality, Health, Safety & Environment engineer

June 2011 - November 2011 (6 months)


Procedures & Technical description review/revision Engineer at Corcovado (Drilling ship) Operator: Cairn Well: Attamik 2. Location: Greenland

- Risk assessment

- Work permit system and Safe Job Analysis

- Care card system

- Focusing on drilling safety: Bit type, drilling parameters, well control/volume control, kick prevention, hole cleaning, mud data & DDR.

- Software: STAR, Mintra & Empreda

- Care philosophy, procedures and procedure exam

Investigated market for best available technology for ”dashboard” system solutions for HSE.

Well control project for Petroleumstilsynet (PTIL) Technical contact with customer relations management system (CRM) and Fast Track project implementation vendor

Data management & generel management

Organized two care for safety seminars and held Care Card presentations with offshore safety officers from Leiv Eiriksson, Eirik Raude, Olympia, Corcovado, Poseidon and Mykonos and onshore QHSE department at Hummeren hotel in Tananger with team building (Gocart racing at Stavanger carting) Safety officer at Olympia (Drilling ship) Client: Vanco Well: Dzata 2A Location: Ghana

Technical contact with information technology vendor and operational performance management and reporting system vendor Page 5 of 23

Project lead: Annual procedure revision/ review

IADC data reporting

KPI reporting

General QHSE engineering and risk management



Mintra administrator


Ocean Rig is an international offshore drilling contractor providing oilfield services for offshore oil and gas exploration, development and production drilling.

I can confirm that we worked well together when Sigve was on board with us. We had some conversations, and he were more than willingly to help me out in any questions related to HSEQ/QA, that i had.

He appeard to be an professional in his profession, and had much experience within the oil business, not only necessarly related to HSEQ/QA. Best regards

Raymond Øren

Electrical section leader

Stavanger Offshore Technical College


August 2009 - December 2009 (5 months)

Stavanger Area, Norway

• Production technique 1 & 2

• Drilling technology

• Geology and formation evaluation

• Health, Safety and Environment for the oil industry

• Well control

• Drilling fluids

• Operating and control systems

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• Mathematics

• Chemistry prosess

• Alternative energy

Oilfield Technology Group

Production Engineer consultant

November 2008 - July 2009 (9 months)

Bergen and Forus (Sandnes)

Production engineer consultant. Client: StatoilHydro (Grane) Responsible for:

• Production engineering

• Well testing and analysis using SAP. Displaying results in Oil Field Manager.

• Production analysis with Flow Manager

• P&I plan

• Production optimizing with GORM

Sub sea technology development team work

Hazid meeting Snorre project. Client: GDF Fabricom Project leader: Analyzing drilling waste management market for SWATH The OTG Group is providing services, competence and products to the global petroleum industry.

Our core services are Field Operations, Drilling & Well Management, HSE

& Offshore Safety Management, Emergency Preparedness, Project and Risk Management, Engineering Support, Software Products and Software Development.


Johannes Waarseth-Junge

CEO 3R Innovation

Talisman Energy

Production Engineer

March 2007 - October 2008 (1 year 8 months)


Production engineering:

Project leader: Responsible for improving oil production at Varg Sub project leading: Subsurface within integrated operations (TENAS operation project)

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Production supervising with PI process book designing and real time allocation programming with PI excel

Responsible for:

• Annual and monthly reports

• Well allocation including production analysis

• Well testing and well test analysis

• Weekly production & injection planning and morning meetings with the communication tool GoToMeeting

• Real time production analysis with PI process book

• Production optimizing with Prosper and GAP

Planning well operations:

• Mechanical operations: Increased oil production from 600 Sm3/d to 1200Sm3/d in a well by increase reservoir pressure by increasing water injection and changing the choke and reduce the pressure drop, stabilized 2 slugging wells by changing gas lift valves (Stabilized total production)

• PLT, Water shut of and perforations (Increased oil production from 100 Sm3/ d to 250 Sm3/d).

• Production optimizing including field visits offshore at Petrojarl Varg and Varg A

• Event organizing: Organized presentations and a seminar

• Production forecasting

• Technical contact with vendors


Varg is an oil field to the south of Sleipner Øst in the central part of the North Sea. The field has been developed with the production vessel, “Petrojarl Varg”, which has integrated oil storage connected to the wellhead facility Varg A. Reservoir

The reservoir is in Upper Jurassic sandstones at a depth of approximately 2 700 metres. The structure is segmented and includes several isolated compartments with varying reservoir properties.

Recovery strategy

Recovery takes place by pressure maintenance using water and gas injection. The smaller structures are produced by pressure depletion. All the wells are producing with gas lift.

Reference: Ivar Garnes

Badger Explorer

Consultant from IOR Chemco

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January 2007 - February 2007 (2 months)


Consultant: Project within petrophysics and geology. Data collection and data base development.

The Badger Explorer is a revolutionary method to obtain subsurface data for oil&gas exploration, mapping of hydrocarbon resources and long-term surveillance.The Badger Explorer drills and buries underground, carrying a unique package of logging and monitoring sensors, at a substantially lower risk, cost and complexity of utilising an expensive drilling rig. The tool penetrates the sea bed and the subsurface by using a mechanical drill bit driven by an electrical motor to loosen and crush the formation ahead of the tool. The crushed formation is transported through the device and deposited in the void behind the tool. The tool carries an electrical cable, which is spooled up inside the unit, connected to the surface and powers the electrical motors. The same cable is used for continous transfer of data back to the surface. IOR Chemco

Reservoir engineer

January 2006 - February 2007 (1 year 2 months)


Analyzing of the world marked (High water cut reservoirs and sand producing reservoirs)

Consultant at Badger Explorer.

Representation at ONS

Reporting (Inteligel progress at IRIS) to Norwegian Research Council, Total, Statoil and Norsk Hydro

Screening of Espoir operated by Canadian Natural Recourses 05-11.06 Project research: at International Researh Institute of Stavanger

• Field manager: mGel reservoir stimulation for increased oil recovery at Gullfaks C including: Quality assurance of treatment, photographing onsite and reporting

• Application to ONS innovation award (Was nominated to the award)

• Articles published at OTC (Offshore & Energy) and ONS (Scandinavian oil and gas magazine)

• Representation at IOR 2006 in Tulsa Oklahoma (SPE)

• PowerPoint designing for sales meetings and reporting Page 9 of 23

• Presentation for potential customers in Aberdeen

• Contact developing (Gained 15 business meetings with oil companies such as Maersk oil, Venture production, CNR international, Amerada Hess in Aberdeen and Talisman-Energy in Stavanger over a short period)

• Marked analyzing of the British shelf (High water cut sand reservoirs)

• Screening of projects including well log investigation and reservoir evaluation: Brage (Norsk Hydro), Gullfaks (Statoil)

Improved Oil Recovery Chemical Company

- a new IOR Chemical Solution Provider

- a start up based on Best of Breed from The International Research Institute of Stavanger (IRIS - former Rogaland Research, RF) extensive research history in the field

- based in Stavanger - the oil capital in Norway

International research institute of Stavanger

Consultant from IOR Chemco

May 2006 - November 2006 (7 months)


Project research: Optimisation of IOR Chemco`s mSand technology

(chemicals for sand consolidation):

Petrophystical measurements: PV, permeability, porosity and RRFw Article:

Forskning: IRIS - International Research Institute of Stavanger - is a recognised research institute with high focus on applied research, equally owned by the University of Stavanger and the regional foundation Rogalandsforskning. IRIS was established in 2006, as a result of a technical re-structuring of the ownership of Rogaland Research.

Rogaland Research was established in 1973, and the continuation of its activities in IRIS provides IRIS with a long and proud history right from the start. Research activities started in the area of social science, but quickly developed to include petroleum.

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Today IRIS remains an independent research institute with research and research-related activities in petroleum, new energy, marine environment, biotechnology and social science and business development. Geoservices

Mudlogger geologist

January 2003 - December 2005 (3 years)

Offshore Norway

• Functioning as Dataoperator/ Secure safe well drilling

• Well monitoring: Pit volume control and gas control

• Maintaining sensors and repairing equipment

• Reporting of geology

• Geology: Catching samples, lithology analyze, cuttings and cavings description and calcimetry analysis and core handling

• Logistics: Sending equipment and samples onshore When working for Geoservices I was working indirectly for Lars Johan Skjold

(Statoil) many times. When he was coming to our working area he asked me for the answer to the geological interpretation. He also told me that the best geologists were engineers because we described what we could see. The geologists were describing what they thought they could see. Arie Romer wrote the following about me: Sigve has executed his work tasks to our full satisfaction and therefore we give him the best recommendations. Geoservices is the industry leader in mud logging, focusing on drilling support and formation evaluation. Decision-ready information about well status is helping to drill better wells more efficiently. Timely and more accurate information on reservoir fluid composition and lithology is detecting pay zones that would otherwise be missed, assisting well placement, revealing reservoir connectivity and compartmentalization, and guiding critical decisions. Drilling Support

Obtain improved quality and higher level of analysis of surface data including drilling speed, vibrations, hole cleaning, and early kick detection to enhance safety and optimize drilling operations.

Formation Evaluation Services

Use analysis of rock cuttings and gas in the drilling mud for understanding formation geology, efficient hydrocarbon detection under all conditions Page 11 of 23

including in deepwater and harsh environments, downhole fluid characterization, early information on reservoir fluid composition, lithology logs, and isotope logging.

Reference: Arie Romer


11 months

ML geologist consultant from Geoservices

2005 - November 2005 (11 months)


Geology evaluation and supervision when drilling the wells: Ula (7/12-A-5 B & 7/12-A-05B-T2)

Ula (Norwegian: Ulafeltet) is an offshore oil field located in the southern Norwegian section of North Sea along with Gyda, Tambar and Tambar East fields making up the UGT area, usually attributed to DONG Energy's main areas of exploration and production activity. The Ula field was discovered in 1976 and came online in October 1986. It contains confirmed 69.98 million m3 of oil and 2.5 million of NGL.


BP is the operator of the field with 80% of interest in the project. BP's partner DONG Energy holds 20% of interest. DONG Energy increased its initial share of 5% to 20% by acquiring Svenska Petroleum's complete share of 15% for

$130 million in 2008.


Ula is located in approximately 70 m (230 ft) of water. The main reservoir stands at 3,345 m (10,974 ft) in the Upper Jurassic Ula Formation. The field has three conventional steel facilities with production, drilling, living quarters. It has 7 production and 2 water injection wells. Current production at Ula field is 10,000 bbl/d. The existing gas process plant was recently extended with a new module, turbin and compressor and has been operative since 2008. The gas from Blane field is injected into the Ula reservoir for production. The gas produced at Ula field is re-injected into the field for increased recovery as well. The field is expected to be abandoned in 2028. The produced oil is then transported by a pipeline to Ekofisk oil field and on to Teesside for refining. In Page 12 of 23

2009, Aker Solutions was awarded a contract to tieback Ula field to Oselvar field. The work is expected to commence in 2011. Once complete, the oil from DONG-operated Oselvar field which is 24 kilometres (15 mi) from Ula will be pumped to facilities at Ula for processing.

ML geologist consultant from Geoservices

2005 - November 2005 (11 months)

Vallhall IP

Geology evaluation and supervision when drilling the wells: Vallhall IP (2/8-G-10 T3 & 2/8-G-11-T4/TS)


Valhall is an oil field located in 70 metres of water. The field was originally developed with three facilities, but has now 8 platforms. The Valhall complex consists today of six separate steel platforms for quarters, drilling, wellheads, production, water injection, combined process- and hotel platform respectively. These platforms are bridge-connected. In addition the field has two unmanned flank platforms, one in the south and one in the north, both around 6 kilometers from the field center.

The Drilling Platform (DP)

Situated between QP and PCP. It has 30 well slots, waste injection and a drilling rig. The platform started its activity on 17 December 1981, at that time with the first covered derrick. The derrick and drilling foundation were removed during summer 2009 and a separate program for plug and abandonment is under development.

The Production Platform (PCP)

The final shut in of the platform took place late July 2012 and the production now takes place on the new process and hotel platform The original PCP platform was built to process 168,000 barrels of oil and 350 million cubic feet of gas per day. The platform is 65 meters high and weighs 21,000 tons. The oil production is piped to 2/4-J at the Ekofisk Center and goes to Teesside in England. The gas is transported directly via Norpipe pipeline to Emden in Germany. The platform also processes oil and gas that comes from Hod. The Wellhead Platform (WP)

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Installed in April 1996 and first oil production started in June the same year. WP has 19 well slots. Total cost, including drilling of the wells, is approx. 1,5 billion NOK.

Norsk Hydro

ML Geologist consultant from Geoservices

2005 - October 2005 (10 months)

Transocean Leader

Wellbore history

Well 6605/8-1 is an exploration well on a Late Cretaceous Lysing prospect situated on the western flank of the Fles North rotated fault block structure in the Vøring Basin outside Mid Norway. The primary objective was to test the presence of movable hydrocarbons in the Lysing prospect. A secondary objective was to investigate the reservoir potential of the Nise Formation Operations and results

Wildcat well 6605/8-1 was spudded in 838 m water depth with the semi- submersible installation Transocean Leader on 14 June 2005 and drilled to TD at 4513 m in Late Turonian sediments of the Lange Formation. Operations went without significant technical problems. No shallow gas or shallow water flow was observed. The well was drilled with spud mud down to 2500 m and with KCl/Polymer/Glydril mud from 2500 m to TD.

The well penetrated the main target at 4184 m, a 70 m thick Lysing Formation deep-water turbidite sand of Early Coniacian age. Gas was recorded from 4180 m. There were two gas zones separated by a water zone. The upper zone had gas down to a free water level inferred at 4221 m (4193 m TVD MSL). The lower gas zone, at 4253 m, was very thin and was approximately 20 bar overpressured compared to the upper zone. Gas shows were also encountered in Early Campanian Nise siltstone at 3064 m and a deeper Lysing sandstone unit at 4354 m.

One 9 m long core was taken in the interval 4190-4199 m in the upper Lysing reservoir. It contained sandstones interbedded with thin mudstone layers. MDT fluid samples were taken at 4230.55 m (water), 4231.4 m (water), 4209.4 m

(gas), 4211.86m (gas), and at 4253.5 m (gas which gave a dark brown/black liquid when flashed). An MDT run in cased hole after the DST and almost 3 weeks after the last mud circulation gave a maximum temperature of 146 deg C at 4230 m. This was believed to be close to the true formation temperature. The well was perm. abandoned 22 October as a gas discovery. Statoil

ML geologist consultant from Geoservices

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April 2003 - September 2005 (2 years 6 months)

Geology evaluation and supervision when drilling the wells: Deep Sea Trym (24/10-M-3BH)

Stena Don (6608/10-B-4BH)

West Alpha (6506/11-P-3 H) Kristin field: Gas/condensate producer Kristin platform was installed in the field in March 2005, and production from the field started on 3.11.2005. Today, 12 wells in production. Full production was reached in 2007 with a daily production rate of approx. 18 million Sm3 gas and condensate daily rate of approx. 17000 Sm3


ML geologist consultant from Geoservices

April 2003 - September 2005 (2 years 6 months)

Snorre B

Geology evaluation and supervision when drilling the wells: Snorre B (34/4- I-1H cuttings injection & 34/4-K-7 H water injector) Snorre is an oil platform in Block 34/4 on the Snorre field in the North Sea. The platform was built by Aker Stord and started production in June 2001. Snorre B is an integral semisubmersible drilling, production and accommodation platform, located about seven kilometers north of Snorre A. The produced oil is transported by pipeline to Statfjord B for storage and export. Some of the gas is reinjected into the reservoir, while the rest is piped to the Prime Pipe system via Snorre A.

The platform was originally operated by the Norwegian Hydro and now operated by Statoil.


ML geologist consultant from Geoservices

April 2003 - September 2005 (2 years 6 months)

Transocean Searcher at Åsgard

Geology evaluation and supervision when drilling the wells: Transocean Searcher (6506/12-Q-2H (Åsgard))

Åsgard is located in the Norwegian Sea, about 200 kilometers from the coast of Norway and 50 kilometers south of Heidrun.

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Åsgard A vessel was in position 8 February 1999 and to start oil production 19 May. Åsgard B is a semi-submersible facility that treats gas and condensate. It came on stream 1 October 2000. Åsgard C is a storage vessel for condensate related to the field.

Åsgard consists of Midgard, Smørbukk and Smørrbukk South. In addition, gas fields Mikkel and Yttergryta linked to the infrastructure in Åsgard. Midgard is located in blocks 6507/11 and 6407/2. Smørrbukk and Smørrbukk South is located in block 6506/11.

Saga proven Midgard in 1981. Statoil found Smørrbukk in 1984 and Smørrbukk South in 1985. In 1995 the rights to the field coordinated in a new structure with Statoil as operator.

The largest development on the Norwegian Continental Shelf Overall Åsgard among the largest developments on the Norwegian continental shelf with its 56 production and injection wells in 17 templates. The water depth in the area is 240-310 meters.


ML geologist consultant from Geoservices

April 2003 - September 2005 (2 years 6 months)

West Navigator

Geology evaluation and supervision when drilling the well: West Navigator (6507-3-4)

Wellbore history:


Well 6507/3-4 is located on the Alve structure, which is a horst, located in the north central part of block 6507/3 on the Dønna Terrace. The main objective of this appraisal well was to prove down flank oil resources in the Middle Jurassic sandstones of the Garn and upper Not Formations. The secondary objective was to prove oil in the Ile Formation.

Operations and results

Well was spudded with the vessel West Navigator on 14 March 2004 and drilled to TD at 4092 m in the Early Jurassic Åre Formation. The well was drilled with seawater and bentonite down to 1250 m, with KCl/polymer/glycol from 1250 m to 2300 m, and with oil based mud (Paratherm) from 2300 m Page 16 of 23

to TD. A shallow gas warning class 1 was given for the interval between 950 to 1370 m, based on gas peaks observed in well 6507/3-1. A pilot hole was drilled down to 1250 m. No shallow gas was observed. The well penetrated the reservoir below the hydrocarbon-water contact in the Garn, Not and Ile Formations. Top Garn Formation was encountered 7 m below prognosis. Moveable hydrocarbons were not proven, only shows throughout the Garn and Not Formations and discontinuous weak to moderate shows in the Ile, Ror, and Tilje Formations from 3805 m to 4000 m. Two cores were cut in the Garn, Not and Ile Formations and nine MDT water samples were collected in Garn, Ile and Tilje Formations. The Garn sample from 3726 m contained approx 2 dl of hydrocarbon fluid, which proved to be mud filtrate

(base oil) with some dissolved residual oil from the formation. The well was permanently abandoned on 30 April 2004 as a dry well with shows


No drill stem test was performed


ML geologist consultant from Geoservices

April 2003 - September 2005 (2 years 6 months)


Geology evaluation and supervision when drilling the well: 34/11-A-11 Kvitebjørn


Kvitebjørn is a gas condensate field located in the eastern part of the Tampen area, in the northern part of the North Sea. Water depth in the area is about 190 metres. The field is developed with an integrated accommodation, drilling and processing facility with a steel jacket. An amended PDO for Kvitebjørn was approved in December 2006.


The main reservoir consists of Middle Jurassic sandstones of the Brent Group. Discoveries have also been made in the Cook- and Statfjord Formations. The reservoir lies at a depth of approximately 4 000 metres and initially had high temperature and high pressure. The reservoir quality is good. Recovery strategy

The field is recovered by pressure depletion.


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Rich gas is transported through a dedicated pipeline to Kollsnes, while condensate is transported in a pipeline tied to the Troll Oil Pipeline II for onward transport to Mongstad.


Drilling on Kvitebjørn is challenging due to depleted reservoir pressure. A new infill well was drilled in 2012

Contact this candidate