Maurel & Prom: Update on Mafia Deep Drilling

By Maurel Prom, PRNE
Tuesday, March 16, 2010

PARIS, March 17, 2010 -

    TANZANIA: Bigwa Rufiji Mafia exploration license

    Maurel & Prom         60% operator
    PetroQuest            20%
    Hollick               20%


Mafia Deep drilling began 4 August 2008. The initial target
depth was 4,600 m. While drilling was underway, interpretation of well data
led to the reinterpretation of the seismic data and the target was changed to
approximately 5,600 m depth. The gas targets represented 5 TCF or 830 MBOE at
100%, or 436 MBOE as Maurel & Prom share net of royalties.


A depth of 3,050 m was reached on 22 November 2008. The Group
then drilled a series of sidetracks to reach a final depth of 5,632 m on 30
August 2009

During drilling, the depth of the wellbore forced the teams to
very frequently cope with temperatures that are exceptional for the oil
industry (over 255 degrees C or 500 degrees F) and pressures of 10,000 psi,
imposing long delays for each operation. Drilling and testing equipment could
not operate in a normal manner in these conditions, and the Maurel & Prom
teams were challenged to create the necessary innovative techniques to
complete the drilling successfully, while respecting safety standards.


    Three areas of interest were highlighted during drilling:

    - The deep zone (from 5,519 m) was first reached on 5 May
      2009. Drilling conditions made well control difficult. Thus, a number
      of plugging agents were injected to creating an impenetrable barrier,
      fracturing and acidizing being ineffective at such temperatures. It was
      therefore impossible to test this zone and its potential remains intact
      and unknown.
    - The logs of the intermediate zone confirmed the existence of
      a gas column 600 m thick in a fractured formation, and the existence of
      a column with a total thickness of 110 m in low porosity sandstone
      reservoirs. As this gas appeared through a fault system, that was not
      the objective, it was always sealed with large quantities of suitable
      products and barytes during the drilling phase. That is why
      perforations produced insignificant quantities of gas - less than 1

Nevertheless, by adding up the volumes at the various
impregnated heights, the recoverable gas for this zone could be quantified at
about 4 TCF. To confirm the quality of these resources, the Group is going to
instruct an independent expert to assess the quantities of recoverable gas
under satisfactory economic conditions.

    - Tests carried out in the upper zone showed a good-quality
      reservoir, with low flow potential (100 to 160 boepd of filtrate) due
      to the formation being penetrated during drilling. This low flow rate,
      coupled with the time that would be needed to install a pump, led to
      the decision to demobilise the Caroil 14 rig and test this zone using
      a crane. Given the losses noted, the quantity of filtrate entering and
      permeating the formation has not been very precisely determined, and it
      may take several weeks to determine the nature of the fluid in this
      formation (water or hydrocarbons). At this stage, the Group has not
      yet evaluated the extent of the possible reservoir.

The presence of oil would allow for rapid cash flow generation.

The Mafia Deep well is today considered to be a stratigraphic
well drilled in a new basin that could be transformed into a commercial well
(oil or gas).


During drilling, the Mafia wells showed indications of
hydrocarbons in Eocene, Paleocene and Cretaceous sandstone reservoirs.

1) Between 1,968 and 1,989 m, a sandstone layer showed gas (up to 12%)
and points of active yellow fluorescence in the Eocene. Continual losses of
mud began to be registered after drilling at this level and continued (>0.4
m3/h) until a 13-3/8" casing was installed. Nothing was logged at this level.
This zone could develop an oil potential of 17.6 MBOE/kmsquared.

    Surface  Useful  Volume  Porosity     Oil      Volumetric  OOIP  OOIP
             Height    of             Saturation   Factor (bo)

      km2      m      MM m3                                    MM m3 MBOE

       1      20       20      0.2       0.7           1        2.8  17.6

At this stage, the Group has not yet evaluated the extent of the possible

2) Based on the 4,200 m reading, numerous and very high indications of
gas appeared in the Cretacious layer (to saturation point in the gas
detectors), which led to the mud density during drilling to be increased from
1.09 to 1.26 to retain well control. Increasing the mud weight weakened the
geological formations and caused large losses of mud that were controlled
only by large steady volumes of lost circulation materials (LCM).

At 5,519 m, gas pressure became so high that to regain control of the
well and allow parameters to be logged, a barite mud plug with a density of
1.6 had to be injected between 4,300 and 5,519 m.

    The logs show:

    - A fractured silt-clay zone 600 m thick between 4,200 m and 4,800 m
      along with some layers of low-porosity sandstone (<10%). Assuming a
      fracture porosity of 0.005%, this zone would develop a gas potential
      of 0.024 TCF/km2.
    Surface   Useful   Volume   Porosity      Gas       Volume    GGIP   GGIP
              Height     of               Saturation  Factor (bg)

     km2        m      MM m3                                      MM m3  TCF

      1        600      600      0.005        0.8       0.0035    685  0.024

At this stage, seismic interpretation identified a surface area of some
160 kmsquared.

    - An argillaceous zone intercalated with sandstone layers between 4,800 m
      and 5,519 m and presenting a sandstone reservoir with a total thickness
      of 110 m with low matrix porosity (<5%). This zone is in the Lower
      Cretaceous (Kipatimu formation).

A cement plug was inserted between 5,519 and 5,134 m to hold
the well and 7" casing was lowered to 5,115 m and cemented (to 4,250 m) in
order to restart 6" drilling.

3) 6" drilling was restarted from 4,950 m (a sidetrack from a window at
the base of the 7" casing) to 5,519 with a mud density of 1.21 (lower density
than used in the 8-1/2" phase at the same depth) causing high losses of mud
which was controlled by injecting large volumes of LCM. No gas observed
during drilling in this phase.

From 5,519 m and to the final depth of 5,632 m, mud density
was increased to 1.26 to contain powerful pockets of gas (saturating the gas
detectors). High mud losses were also encountered and controlled by injecting
large volumes of LCM. Drilling was halted at 5,632 m as it was technically
impossible to continue deeper given the pressures and temperatures reached in
the wells.

The logs recorded before inserting 4-1/2" caps could not read below
5,136 m.

    The logs show:

    - An argillaceous zone intercalated with sandstone sequences between
      4,950 m and 5,519 m with a total thickness of 85 m of low-porosity
      Sandstone (<5%) and conforming at all levels with the data from phase
      8-1/2" drilling.
    - A zone between 5,519 and 5,632 m with a total reservoir thickness of 15
      m with low matrix porosity (<5%).

This document may contain projections about the financial
condition, results, activities and industrial strategy of Maurel & Prom. By
nature such statements involve risks and uncertainties to the extent that
they are based on events or circumstances whose future outcome is uncertain.
These forecasts are made on the basis of assumptions that we believe are
reasonable but which could ultimately prove inaccurate and are subject to
certain risk factors such as changes in the price of crude, the effective
rates of oil production and associated costs, operational problems, political
stability, legislative or regulatory reforms, war, acts of terrorism or

    Maurel & Prom is listed on Euronext Paris - Compartment A-CAC Mid 100

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