Block Altamira - Contratos Integrales EP

Transcription

Block
Altamira
EXECUTIVE SUMMARY
Asset Poza Rica-Altamira
INDEX
1. Introduction
2. Basin description
3. Main characteristics
4. Exploration and development history
5. Production by field and reserves
6. Facilities and hydrocarbons management
7. Drilling practice
Asset Poza Rica - Altamira
INTRODUCTION
The Altamira block is located in the costal plane of the Gulf of Mexico, approximately 40
Km NW of the city of Tampico, in the south side of the state of Tamaulipas. It covers an
area of 1,625 Km². Geologically it is located in the northern portion of Tampico-Misantla
Basin.
Location of the Altamira Block
Eighty seven (87) wells were drilled in the block, of which twenty five (25) are operating,
eighteen (18) are shut-in and forty four (44) are plugged and abandoned.
The Altamira block has cumulative production of 104.29 MMb of oil and 103.32 MMMcf
of gas. To-date it has produced 13.618 MMb and currently is producing 1,100 MMB/day.
The crude produced is heavy oil with density varying from 10° to 13° API. Current
reservoir pressure varies from 50 to 55 Kg/cm2.
Production in the Altamira Block started in 1926 from naturally fractured shaly-limestone
rocks of the Upper Cretaceous San Felipe and Agua Nueva formations. Impregnated bed
thicknesses vary from 150 to 190 meters.
The drilling difficulty is considered low; there are 700 km of 2D seismic of average quality.
BASIN DESCRIPTION
The Tampico-Misantla Basin is located west side of Mexico and includes the south end of
the state of Tamaulipas, the central portion of the State of Veracruz, portions of the west
side of the states of San Luis Potosi and Hidalgo, the north portion of the state of Puebla
and the continental platform to the bathymetry of 200 meters.
Block Altamira
Location of the Block Altamira in the Tampico-Misantla Basin.
The crystalline basement is made up of igneous and metamorphic rocks ranging from the
Permian to the Middle Jurassic. In stratigraphic column of the Tampico-Misantla Province
the following tectonic sequences are recognized:
The first tectonic sequence (Synrift) begins in Triassic with the deposition over the
basement of continental clastic rocks of alluvial and fluvial environments with some lava
flows of the Huizachal Formation of the Late Triassic and Hettangian age. It is followed by
a marine transgressive sequence of sandstones and shales of the Huayacocotla Formation
during the Lower Jurassic Hettangian-Pliensbachian. In the Middle Jurassic the continental
environments re-appear with the clastic rocks of the Cahuasas Formation. A new
transgression allowed the deposition of oolitic limestone in the lower portion of the
Huehuetepec Formation.
BASIN DESCRIPTION
Sandy limestones and shaly bioclastic rocks of the Tepexic Formation were deposited over
these formations in the Callovian age. It was followed by the deposition of deep water shaly
and carbonate limestones of the Santiago Formation when the maximum transgression was
reached during the Oxfordian age. Around of highs of the basement, carbonate ramps
developed and, in their internal side, were deposited the shaly-sandy limestones of the San
Pedro Formation and the oolitic limestones of the San Andres Formation together with
their lateral equivalents of the Chipoco Formation and basin sediments of the Taman
Formation. These facies reached their maximum development during the Kimmeridgian age
covering the Tampico-Misantla basin, mainly during the second sea-level lowering. In
certain zones it can be observed the abrupt change of the Santiago Formation to the
Chipoco or San Andres Formation.
The shaly and carbonate limestones of the Pimienta Formation covered regionally the
formations Taman, Chipoco and San Andres during the Tithonian. Toward the end of the
Jurassic a thin packet of clastic rocks are deposited over the Pimienta Formation. These
sediments make up the La Casita Formation and their source is the erosion of exposed
portions of the crystalline basement.
The second tectonic sequence (Passive Continental Margin) begins with the deposition of
oolitic and bioclastic limestones of lower member of the Tamaulipas Formation of the
Berriasian-Valanginiano age. Towards the area of Tuxpan, however, there was the
development of a reef represented by the limestones of the El Abra Formation bordered by
slope sediments of the Tamabra Formation.
Towards the end of the Cenomanian this platform has an extended surface exposure. With
the following transgression, the shallow-water carbonate sedimentation is re-established
with the relative rise of the sea level. The pelagic carbonate limestones of the Agua Nueva
Formation of Turonian age are deposited over the formations El Abra, Tamabra and Upper
Tamaulipas.
BASIN DESCRIPTION
Modelo de depósito Cretácico Medio (Albiano–Cenomaniano).
Later shaly limestones with intercalations of bentonite of the San Felipe Formation were
deposited followed by marl, shaly limestones and calcareous shales of the Mendez
Formation mark the end of the Passive Continental Margin tectonic sequence.
The third tectonic sequence (Foreland Basin) is characterized by a change from carbonate
to terrigenous sedimentation. The terrigenous sediments were defined by López-Ramos
(1956) as being part of the Tampico-Misantla Basin.
The bathymetric profile had the tendency to be of a ramp, with relatively narrow zones,
and in which the costal systems changed to a prodeltaic or slope zone with predominant
transport of sediments by turbidity currents, flows of waste rock and landslides.
List of formation abbreviations:
Mendez
San Felipe
Agua Nueva
Upper Tamaulipas
Lower Tamaulipas
Upper Jurassic
Upper Jurassic San Andres
El Abra
Kmendez
Ksf
Kan
Kts
Kti
Js
Jsa
Ka
MAIN CARACTERISTICS
In this block there are 700Km of 2D seismic of which 82.8 Km have been re-processed.
The quality of the seismic information varies considerably and the coverage of the area is
irregular. Additionally there are groups of lines that do not intercept causing some
difficulties to the interpretation. There are also many crossing errors and it is
recommended to re-process all the seismic data.
The seismic response of the San Felipe Formation (Ksf) is poor except in a few lines in the
central part of the seismic survey. Agua Nueva Formation (Kan) has a reflection of average
amplitude and continuity. Upper Tamaulipas (Kts), Lower Tamaulipas (Kti) formations and
Upper Jurassic (Js) are good reflectors and therefore easier to correlate. The interpreted
basement is given by two high-amplitude events. In the high-structural areas the
basement loses amplitude and its interpretation is more complex.
Seismic line; left side is the Original line; right side is line reprocessed (Stolt Migration)
Ksf
Kan
Kts
Kto
Kti
Typical seismic line Block Altamira
MAIN CARACTERISTICS
The main and most important reservoir in the area of San Felipe-Agua Nueva is shallow
(150-500 meters), is part of the Cretaceous play, is made up of rocks from the Upper
Cretaceous and it is the primary economical objective. Due to its environment of
deposition (basin) is characterized by low porosity and permeability. As a consequence of
later events, networks of faults and fractures appeared and they created the effective
porosity and became the path for oil migration to the reservoir. These systems of
faults/fractures are located on the flanks of the anticlines, on the highs of faulted blocks
and also on the synclines.
East-West Transversal Structural Section
Figure shows structure, and tectonic style prevalent in the Block
Synthetic seismograms for the wells Altamira-1009H and Altamira-1022H
MAIN CARACTERISTICS
In the Altamira block three vertical seismic logs (VSP) were acquired for wells Altamira1102H, 1003H and 1033; in addition two (2) synthetic seismograms (shown above) were
calibrated and validated for wells Altamira-1009H and Altamira-1022H. According to the
average velocities of the surface of the San Felipe Formation (Ksf), the velocities decrease
from NW to SE. A geophysical model of the block is shown below
Tridimensional view the local model of Altamira showing its “stratification”
The SW-NE stratigraphic section shows that in the Altamira Block there is a thinning of
approximately 30 meters in the thickness of the San Felipe (Ksf) and Agua Nueva (Kan)
formations.
SW-NE stratigraphic section
MAIN CARACTERISTICS
Composite well logs were prepared and were calibrated from results of detailed studies of
cores, calibrated with gamma rays, lithology, grain types, fractures and other data.
Composite well logs generated from detailed studies with cores
AssetAsset
PozaPoza
Rica Rica
- Altamira
- Altamira
EXPLORATION & DEVELOPMENT HISTORY
Altamira-30, the first well drilled in this block, was completed in 1926 and produced oil
from an open wellbore in the interval of 476-379 meters, in rocks of the Upper
Cretaceous. The maximum production of the Altamira Block was 10,170 bpd in 1926 and
currently it produces 1,100 bpd.
The reservoir San Felipe – Agua Nueva produces heavy oil of 10-13° API and viscosity of
300 to 700cp @P&T. It also produce gas with 15 to 25% of C02. The reservoir temperature
varies from 40 to 45 oC and the main drive mechanism is the rock - fluid expansion. The
developed area covers a surface of 8.51 Km2.
The characteristics of the producing rocks are: naturally fractured shaly limestones with
impregnated thicknesses ranging 150-190 meters. The reservoir pressure is low and
intensity of the fracturing determines the productivity; current pressure ranges from 5055 Kg/cm2. The flow is only through fractures. Current recovery factor is 13%, porosity
varies from 8 to 12%, permeability varies from 1 to 1,000 mD.
From 2006 to date, thirty two (32) wells have been drilled. The drilling difficulty is low. Of
the eight seven (87) wells drilled there are thirty five (35) wells with logs. There are
seventy one (71) prospects planned for drilling.
AssetAsset
PozaPoza
Rica Rica
- Altamira
- Altamira
EXPLORATION & DEVELOPMENT HISTORY
Meters
Structural Map top of the Agua Nueva Formation (Kan) showing the location of wells and
proposed prospects
PRODUCTION BY FIELD AND RESERVES
The Altamira block has produced to date 13,618 of MMb oil. The current average production
for new wells is 40 bpd and 9 bpd for old wells. The initial production for new wells is 70 bpd
with a GOR of 60 m3/m3.
The current development wells were initially drilled as outpost wells; due to bad quality of
seismic information the interpretation was performed by inference of the continuity of the
faults in the North, with spacing of even 5 Km. Once the results were confirmed intermediate
prospects with 1 km spacing were documented. In the future and with better information a
reduction in well space is being considered.
The production driving systems are: flowing, mechanical lift and progressive cavities
Production History Altamira Block
Altamira Block Cumulative Production
Altamira Block Cumulative Production
The estimated reserves of the Altamira block, as of January 2011 are:
No. of Wells
87
Fields
Plays
Hydrocarbon
Ksf-Kan
Developed
Area by Field
(Km2)
Heavy Crude
Original Volume
(MMb/MMMcf)
Densidad
(°API)
10-13
Reserves (MMboe)**
1P
2P
3P
2.3
4.8
10.5
Recovery Factor
Total 2P (Fraction)
Cumulative
Production
(MMb/MMMcf)
RGA
(m3/m3)
22
Remaining
Reserves 2P
(MMb/MMMcf)
OIl
Gas
Oil
Gas
Oil
Gas
Oil
Gas
Altamira
8.4
103.19
103.19
0.18
0.17
13.6
17.3
4.7
0.52
Ébano
0.11*
1.1
0.13
0.09
0.08
0+
0+
0.1
0.01
Total
8.51
104.29
103.32
0.18
0.17
13.6
17.3
4.8
0.53
** Gas was not included because it contains a high percentage of CO2; it is not commercialized
* Fraction of the area of the Ébano Field that is included in the Altamira Block
+ Non-productive wells with no cumulative production
FACILITIES & HYDROCARBONS MANAGEMENT
Currently the production management is done using three (3) oil gathering stations. The
production from stations Altamira-30 and Mata-del-Muerto is trucked using tank-cars to the
Tamaulipas-3 battery station where is pumped to central storage and pumping facility (CAB)
Tamaulipas for dehydration. Later to the storage tanks of the Madero Refinery. From the
refinery it goes to tankers for exporting. The infrastructure capacity for the storage of
hydrocarbons is 15,000 bpd.
Production Facilities Data
Oil Gathering Stations
3
Storage Capacity
15,000 barrels
Pipelines:
Diameter (“)
Length (Km)
Oil (1)
6
6
Gathering Lines (14)
2 -8
14
Gas Gathering Stations
Do not exist
Facilities Map
Enclosed below
Table of the Production Facilities Infrastructure
The following diagram shows the production facilities in the Altamira Block:
BLOQUE ALTAMIRA
Altamira 30
Mata del Muerto
Pimienta
BLOQUE ÉBANO
Ébano 4
Corc. 1Sabalo
Raya 5
E-114
E-112
Chijolito
Chijol-D-17
Ébano 3
E-41
Ébano, SLP
Méndez 2
Corc. 5 Águila
Corc. 2 Águila
E-M
G-Méndez
E-K
E-P
Chila-Salinas
Paciencia
4 Sinclair
6 Internacional
E-108
A-21
3 Sinclair
V Águila
IV Águila
2 Calentadores
3 Sinclair
E-104
Cacalilao 150
274 Internacional
VI Águila
II Águila
III Águila
H2- Marland
Cacalilao, Ver.
5 Sinclair
Limón 12
6 Sinclair
Dominguez
Limón 5
I Águila
Mahuaves
Salvasuchil
Ojital
Barberena
Vega de Otates
Limón 13
San Manuel
Piedras
Palangana
Buenavista
Tanantoro
Pánuco, Ver.
Minerva
BLOQUE PÁNUCO
Sentido del Flujo
DRILLING PRACTICES
Types of Wells
The drilling plan considers three possible designs to reach the objective. The design
chosen for each well depends on the information from geological, geophysical and
reservoir petrophysics sources available at the drilling time
Well type l
Horizontal, without pilot
vertical hole,
information taking and
horizontal drilling to
900 meters (md).
Well type ll
Horizontal, with
vertical hole to 470 m.
Information taking and
horizontal drilling
to 900 md.
Well type lll
Horizontal, with
vertical hole to 950 m.
Information taking in
deep reservoirs and
horizontal drilling to
900 md.
Well Type I: This design is used when a well is located in a area where there is precise
knowledge of the formations depth and structural setting; this allows to drill a horizontal
directly to the objective without the need to evaluate, through information taking, the
wellbore trajectory .
Well Type II: This design is used where precise knowledge of the formation and structural
setting are not available. Therefore it is necessary to drill a pilot vertical hole until the
appropriate depth is reached and later design the horizontal wellbore trajectory.
DRILLING PRACTICES
Well Type I: This design is for strategic wells located in areas where there is no precise
knowledge of the depth of the objective formations and of where other deeper reservoirs
may exist; in this design a deeper pilot vertical well is drilled.
Later the vertical well is abandoned and a new horizontal wellbore trajectory is designed
to reach the objective. In this type of design conventional and special well logs suites are
taken. In addition cores are taken and formations tests are run to help characterize the
reservoir statically and dynamically.
Cementing Program:
Cementing Program
9 5/8”
0 to 18 m.b.m.r. (meters below rotary table)
7”
0 to +/- 250 m.b.m.r. (meters below rotary table)
Mud Program:
Mud Program
1ª Phase
0–48 m
Water based fluids
(1.02-1.10 gr/cm3)
2ª Phase
48-250 m
Water based fluids
(1.02-1.15 gr/cm3)
3ª Phase
250-TD m
Potassium Brine
(1.02-1.06 g/cm3) with balanced rig
(1.02-1.06 gr/cm3)
4ª Phase
250-TD md
Potassium Brine
(1.02-1.06 g/cm3) with balanced rig
(1.02-1.06 gr/cm3)
DRILLING PRACTICES
Reservoir pressure:
50 to 55 Kg/cm2 bottom-hole pressured, closed
Type of Completion:
Single, open hole producing interval
Stimulations:
Cleaning treatment with organic acid
Artificial lift:
Mechanical pumping and progressive cavities
Expected production:
70 bpd per well
Block
Altamira
EXECUTIVE SUMMARY
June 2011

Block Altamira - Contratos Integrales EP

Transcription

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