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PERSONAL DETAILS

DATE OF BIRTH:    24th December 1963
NATIONALITY:    German

EDUCATIONAL BACKGROUND

1982 - 1985     IMPERIAL COLLEGE, UNIVERSITY OF LONDON
B. Sc, (Eng) Hons. in Metallurgy & Materials Science, Royal School of Mines


CAREER SUMMARY

Multi-talented, goal driven manager/engineer with a broad base of technical know-how and skills that allows driving fast-track projects from all the angles required to ensure parallel development of engineering, safety concerns, cost control, procurement, construction, procedures and implementation. Ability to tackle new challenges and areas of development not concurrent with background. Team leader who makes the end goal a group driven success. Has tackled some very big challenges in past work including project killers and has the experience to make hard decisions or choices when necessary.

Areas of Experience
Total Cost of Ownership Initiatives
Project Management
Fast-tracking
Parallel Engineering and Execution
Cost vs. Financial Gain / Loss Engineering
Financial Control
Logistic Planning
Early Production Facilities
General Operations Engineering
Fabrication verification    
Underbalanced Drilling Systems
Closed System Drilling
Managed Pressure Drilling
Hostile Fluid Drilling
H 2 S Safety
Overall Safety Plans
QHSE systems
Drill Stem Testing & Production Testing
Tender & Contract Preparation
PVT data verification
Installation Auditing


WORK EXPERIENCE

Jan 01 – current Impact Engineering Solutions Ltd., Operations Manager

•    Operations planning and supervison
•    Development of Patented Technology for Managed Pressure Drilling
•    Advisor to Repsol-YPF on ‘Global Supply Chain Strategy’
•    Facilitator for TCO ‘Total Cost of Ownership’ Initiatives
•    Contracts & Tender Adviser to various clients
•    Advisor on Underbalanced Operations specializing in surface systems and design

Nov 01 – Jan 03        PT Impact Solutions Indonesia
Underbalanced Drilling Project Manager

•    Seconded to ExxonMobil Oil Indonesia Inc.
•    Planned 2nd UBD intervention in Arun gas field
•    Complex UBD through 10” monobore completions with high surface flow rates at very low pressures.

Aug 99 – Dec 00        Impact Engineering Solutions Ltd., UK
Project Manager

•    Joint Industry Project (JIP) ‘Drilling with Lightweight Fluids from a floating drilling installation’.
•    Responsible for the technical implementation
•    Chairing and follow-up of the HAZOP
•    Review and verification of system design
•    Development and review of operating procedures
•    Technical assistance and expertise for integration of drilling rig and surface system
•    Successful implementation carried out in December 2000


OilFlow Consulting Ltd. 1991 – 1999

Mar 99 - Jul 99        Oil Flow Consulting Ltd.
Business Development

Nov 96 – Feb 99        Mobil Oil Indonesia Inc., Sumatra, Indonesia
            Full Time Engineering Advisor
•    Operations Engineering
•    HAZOP preparation
•    Closed System Drilling
•    Sour gas Safety
•    Underbalanced Drilling Systems

Nov 95 – Nov 96        Various early production project bids and studies.

Apr 95 – Oct 95        EPF New Orleans, USA
            EPF Project Manager
    
•    Procurement, construction & commissioning of a Mobile Production Unit (EPF)

Jan 92 - Mar 95        Schlumberger Port Harcourt, Nigeria
            Consultant
•    High Rate Testing
•    15K psi Pressure Control
•    Testing Supervisor
•    Project Manager Integrated Services
•    Project Manager for Enhanced Production of Isobo field.


SCHLUMBERGER 1985 – 1991
    
Jan 91 - Sep 91     Warri, Nigeria
Field Service Manager (Testing)

Feb 89 – Dec 90        Port Gentil, Gabon
•    General Field Engineer
•    Field Service Supervisor for Well Testing and Early Production Services
•    Testing and Production Services, Technical Engineer at District Level
    
Jun 85 – Jan 89        Nafoora, Libya
            Stavanger, Norway
            Gt. Yarmouth, UK
•    Senior Field engineer
•    Field Engineer

PROFESSIONAL TRAINING

1986 - 1991    Internal Schlumberger
-    Course in Well Testing/Drill Stem Testing
-    Nodal Analysis, Interpretation of Well Test Data
-    Course in Downhole Gauge Technology
-    Pressure Control Certification
-    Computerized Data Acquisition
-    Schlumberger Wireline Course
-    Production Logging Course
-    Wireline Perforating, Setting Plugs & Packers
-    Fluid Properties Evaluation and PVT Analysis
-    Tubing conveyed Perforating
-    Drill Stem String/Test Design and Advances
-    Basic Petroleum Engineering
-    Offshore Survival, Firefighting

2001            Effective Negotiation



COMPUTER SKILLS

Proficient with standard office software including MS Project



PUBLICATIONS

1.    “Mobile Production Unit for Offshore Nigeria”, 1996 Mike Guerra, Christian Leuchtenberg (Mobil Oil Publication).

2.    "Development and Performance of Surface Equipment for High Temperature Underbalance Drilling in a Sour, Severely Under Pressured Formation", ASME Energy Sources Technology Conference, Houston, Texas, February 1999. C. Leuchtenberg, P. R. Brand, P. V. R. Suryanarayana, D. Eberhard, P. J. Frink

3.    “System for Drilling an Offshore Shallow Sour Gas Carbonate Reservoir”, SPE/IADC 52808, R. Quitzau, Mobil International Drilling Services; P. R. Brand and B. A. Tarr, Mobil Technology Company; P. J. Frink, Mobil Oil Indonesia; C. Leuchtenberg, Consultant

4.    “Drilling with Aerated Fluid from a Floating Unit. Part 1: Planning, Equipment, Tests, and Rig Modifications,” Paper IADC/SPE 67748, presented at the 2001IADC/SPE Drilling Conference, Amsterdam, 27 Feb-1March, 2001.

5.    “No-Damage Drilling: How to Achieve this Challenging Goal?”, Paper SPE 77189, presented at the 2002 IADC/SPE Asia Pacific Drilling Technology held in Jakarta, Indonesia, 9-11 September 2002.

6.    “Increasing Leakoff Pressure with New Class of Drilling Fluid”, Paper SPE/ISRM 78243, presented at the 2002 SPE/ISRM Rock Mechanics Conference held in Irving, Texas, 20-23 October 2002

7.    “Micro-Flux Control: The Next Generation In Drilling Process”, Paper SPE 81183, presented at the 2003 SPE Latin American and Caribbean Petroleum Engineering conference held in Port-of-Spain, Trinidad, West Indies, 27-30 April 2003.

8.    “Micro-Flux Control: The Next Generation In Drilling Process for Ultra Deep water”, Paper OTC 10562, presented at Offshore Technology Conference in Houston, Texas, USA, 5-8 May 2003.


PATENTS

•    Drilling System & Method, US Application No. 09/737851 filed 18th December 2000, granted May 2003.



LANGUAGES

1.    English (bilingual)
2.    German (bilingual)
3.    French (basic)



MAJOR PROJECTS ACCOMPLISHED

1.    Mobile Production Facility for Mobil Producing Nigeria, 1995.

•    Capacity 40,000 BPD Oil, 20 MMSCFD GAS.
•    Project Manager for Schlumberger Overseas Inc.
•    Contract scope included:

-    Procurement of rig for conversion
-    Conversion of rig and associated engineering
-    Production Top sides EPC
-    Installation and Commissioning
-    Provision of Operators and Maintenance

•    Time from initial discussions to first oil was 212 days
•    Was key player in initial marketing of concept, cost vs. profit evaluation,
with subsequent pricing.
•    Managed all aspects including but not limited to:
    Rig procurement, Financial Control, Topsides Design, Rig Conversion Design, Contracts
    Construction, Classification ( ABS ), Transportation, Installation, Commissioning.
•    Project was a success. Less than 1.8% downtime over 2.5 years of operations.


2.    Development of Severe Lost Circulation, Overpressured Sour Gas Reservoir , 1996-1999.

Three-phase development:    

Phase 1:     Drilling of 9 wells through a sub-sea template.
Phase 2:     Installation of Jacket and Topsides.
Phase 3: Completion, stimulation and clean-up of wells.

Drilling Phase

•    Closed drilling system using Rotating BOP’s, Large Mud Gas Separator, Custom Flaring System.
•    Gas reservoir with 33% CO2 and 2% H2S.
•    Scope included :
-    Design verification
-    Flare Design
-    Procedure verification
-    Installation verification
-    H2S Plan
-    Evacuation and overall Safety Plan
-    DST design
-    DST supervision


Completion Phase

•    Preparation of contracts for coiled tubing, clean-up of wells
•    Design of clean-up layout, equipment spec. for cleaning up 9 wells at rates up to 80MMSCFD
•    Planning of completion rig layout on platform
•    Coordinating with Platform Construction Team and Drilling/Completion department
•    Logistics planning
•    Safety plans, H2S plan during completion phase
•    Design, fabrication and installation of a complete fire-water system and accessories for platform.
(Firewater system was eliminated for production based on risk analysis for unmanned operations. However Completion operations with large numbers of personnel and flammable fuel on board required a fire system)


3.    Pilot Test of Underbalanced Drilling in Arun field and subsequent Drilling of 6 wells, 1998

Underbalanced Drilling was the only viable option to drill in the sour, severely underpressured, ARUN formation in North Sumatra. ARUN was one of the first HPHT fields in the world to be developed (1978). In addition to corrosive environment (60 ppm H2S and 15% CO2), and low pressure (1.8 ppg equivalent), expected downhole temperatures were in excess of 350 degrees F. Moreover, Natural Gas produced in the field was determined to be the only commercially viable gas phase for the gas-water drilling fluid. As a result, development of surface and downhole equipment were two of the major challenges in the implementation of underbalanced drilling.

I was the project engineer instrumental to development, installation and performance of a purpose-built surface system to handle high-temperature, corrosive, gas-water-foam returns. In order to keep the costs under control, existing inventory was used to build the surface equipment in-house. The system therefore uses typical mud gas separators, settling tanks, controls and choke systems to create a fully-closed underbalanced returns-handling system. An innovative recycling cooling system was also designed, in order to cool the returns to allow liquid condensation before separation. The system was installed and used to collect data during the pilot project. It performed successfully and was used to drill 8 wells, and in slightly modified form drilled 4 wells in PASE field.

Key areas that I developed or supervised :

•    Assessment of the drilling rig and modifications necessary to make it safe for UBD
•    Hazop preparation, review of drilling procedures, and other safety issues to pass a full safety review of the project.
•    Supervision of the design, procurement and installation of the equipment. Surface equipment was complex because of the restrictions of operating in a production cluster, between producing wells. Also due to limitations in UBD drilling models for ARUN conditions, a lot of data had to be gathered resulting in data acquisition, process control and command center being run from a control building.
•    Design of the pilot test to ensure that sufficient data was collected to enable successful planning of subsequent drilling.
•    Personnel training, fire protection of site, deluge systems were also part of my scope.

More detail on Pilot Test goals

The ARUN field is a prolific gas and condensate producing carbonate field located in upper Sumatra, Indonesia. The field has been producing for 20 years with peak production exceeding 2,000 MMSCFD. The pressure in the reservoir has dropped from 7600 psi to 900 psi, due to production. Conventional drilling is no longer possible. The last attempt at conventional drilling, in 1995, resulted in total loss of returns and 31 cases of stuck pipe. In an effort to increase production, Mobil Oil Indonesia initiated a study to determine if underbalance drilling was a viable technology for the field.

The environment in the ARUN reservoir posed many problems not encountered previously with UBD. The bottom hole temperature is 354 degrees F. This temperature precluded the use of conventional PDM motors typically used in UBD operations. The temperature also exceeded the limits of wireline directional and pressure sensor tools.


The temperature along with the make up of the produced gas, also raised the question of the correct fluid that should be utilized. In an effort to answer the questions of model accuracy and to determine the correct fluid to be used, the decision was made to conduct a flow test, prior to drilling the first well. The flow test was devised to test multiple fluid types, motors and simulator models to determine the optimum system to be used in the drilling campaign.

A system for handling the return fluid, collecting the required data for analysis and separating the fluid at surface was required. Analysis of commercially available systems showed that they were not capable of handling the anticipated surface temperatures and flowrates at low-pressure heads. Inquiries into the cost of modifying a system and leasing it for the drilling campaign showed that this would be cost prohibitive. The decision was made to develop a purpose built system for the project, using redundant equipment from the ARUN production facility.







4.    Drilling with Light Weight Fluids 1999-2001

In 1998 a Joint Industry Project was formed under the umbrella of the university foundation COPPETEC and Petrobras, the Brazilian state oil company. Members include several major operators and service companies: Amerada Hess, ExxonMobil, Shell, Weatherford, Alfa Laval and Impact. The project aims were the development of technology to deliver the benefits of underbalanced and low head drilling to the floating drilling industry, and in particular deep water.
Impact personnel have been involved from initial conceptualization, and the company became formally involved in the project as members at commencement of Phase II. During this phase my contribution was:
•    Prepare HAZOP •    Chair and follow-up HAZOP •    Chair second HAZOP •    Provide technical advice for implementation of the field test •    Advice and verification of new surface equipment design •    Review of calculations and P&ID's •    Verification of rig installation •    Preparation of detailed procedures •    Close out of HAZOP items
Project Description
An initial Phase I of conceptualization and development was followed up with Phase II, the planning and implementation of a field test of the conceptual system on a semi-submersible drilling unit. The concept developed involved the injection of both drilling mud and Nitrogen through the drillpipe to reduce the overall fluid density to a near balance condition. It was then necessary to cap the drilling riser to divert multi-phase returns through a surface separation system.This involved decoupling the riser at the balljoint, locking the slip joint closed and operating with an unhinged riser configuration.This was a new operation for Petrobras and also utilised some unique equipment developments as outlined below:


1.    Utilisation of a Rotating Control Head to cap the top of the riser whilst drilling in the reservoir.A key difference between onshore and floating vessel applications of light weight fluids drilling is the operational procedures and precautions necessary to control pressures in the riser. The riser is not designed to tolerate high pressures. The semi-submersible rig is equipped with a 21" riser, which has a collapse resistance of 660 psi when full of gas and can tolerate an internal pressure of 500 psi before leaking. For this well the riser can stand full evacuation.2.    Utilisation of a purpose built fluids separation system with a reduced footprint to allow installation within the space limitations imposed by a floating vessel. The design incorporates advanced control technology to handle the variations in flow volume and pressure common during such operations.This system, with the associated new procedures, was an industry first. It involved the installation of several new facilities and modifications to the existing rig equipment. Hence, to ensure the potential hazards were effectively managed and that appropriate controls were put in place, a hazard and operability (HAZOP) assessment was made of the overall installation, procedures and process several months prior to the test.
The Field TestPetrobras XVII was selected as the test rig to drill Albacora 64H development well in the Campos Basin as the test well. Modifications to the rig commenced in June and the test was successfully conducted in December 2000 in 300m of water depth offshore Brazil.
The field test was essentially a dress rehearsal prior to full system implementation. As such the objectives were realistic, aimed at establishing the feasibility of the concept. In summary these objectives were:
•    Test and refine the newly developed operational procedures •    Inject Nitrogen to reduce the hydrostatic head while drilling (while maintaining overbalance) •    Demonstrate the ability to cap the drilling riser •    Test Surface System capacity to handle 3 phase separation: solids, liquids & gas •    Test the total system's capability to handle nitrified drilling fluid •    Collect data for system •    Gain experience in lightweight fluid operations from a Semi-submersible







5. Complex UBD Intervention in Arun Gas Field 2001 - 2003

Based on my previous experience in Arun, ExxonMobil Oil Indonesia Inc. contracted Impact Engineering Solutions and I was seconded to project manage the UBD section of the last new drills in Arun field.

An existing UBD surface handling systems was extensively modified and new procedures developed based on original Arun experience to drill 6 new wells with 9-5/8” – 10” monobore completions.

Reservoir pressure was very low, 400 – 700 psi, but flowrates still very high when drilling up to 25 mm SCFD at 50psi surface pressure. Safety was a key concern and the whole project was completely run under the ExxonMobil Oil Indonesia Inc. OIMS system (Operational Integrity Management System) which was a first full achievement for a complex drilling operation in Indonesia.

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