Integrated Contract EP: Soledad

Transcription

1
Content
Introduction ............................................................................................................................... 3
Basin Description ...................................................................................................................... 5
Main Features ........................................................................................................................... 9
Exploration and Development History ............................................................................. 15
Production by Field and Reserves .................................................................................... 18
Infrastructure and Hydrocarbons Management .......................................................... 19
Drilling History .......................................................................................................................... 22
2
Introduction
The Soledad integrated block is located in the North-Northwest part of the “Activo
Integral Aceite Terciario del Golfo” surface, covering an area of 125 Km2; it is 60 Km NNW
of Poza Rica, Veracruz.
Location of Soledad Block
Geologically, it is located in the South of the Tampico - Misantla basin. Is the only block
with two main fields, Soledad Norte and Soledad; this area was discovered in 1943 upon
drilling the Soledad-1 well, producing from the Tamabra formation, with an initial rate of
44 bpd, 0% water, the well was abandoned after being deemed a non-commercial oil
producer.
492 wells have been drilled on this integrated block; 279 are closed, 27 plugged and 186
are operating. The maximum production was 7,244 bpd oil with 133 active wells in April
1980. Cuurently, (30-06-12) production is 3,403 bpd oil; cumulative production is 39
MMbls oil and 5.7 MMMpc gas. Oil type is light crude; the Soledad Norte field has a
density of 32° API, while it is 37 °API for the Soledad field. The most recent bottomhole
pressure measurement lies between 58 and 125 Kg/cm2. The existing production systems
3
in the area are rod pumps and gas lift. The average depth of the tertiary deposits is 1,200
m in the Tertiary.
Some gas shows were observed and the channel samples and cores exhibited oil
impregnation during the drilling of the exploration wells in the Tamaulipas Superior,
Tamaulipas Inferior, Pimienta, Tamán and Tamabra Mesozoic formations.
The following information was obtained through PVT analyses of the Soledad-101 well as
well as various wells near the Block:
• Cacahuatengo-2 Well (located 8 Km south southwest of block):
Tamaulipas Superior Formation: 26.8 °API Oil; gas solubility at initial pressure
relationship (Rsi) of 85.00 m3/m3; Oil Volume Factor (Bo), 1.2801 m3/m3 and a
saturation pressure (Pb) of 146.80 Kg/cm2.
• Presidente Alemán-772 Well (located 71 Km Southwest of block):
Tamaulipas Inferior Formation: 35.7 °API Oil; gas solubility at initial pressure
relationship (Rsi), 179.50 m3/m3; Oil Volume Factor (Bo), 1.6270 m3/m3 and a
saturation pressure (Pb) of 215.20 Kg/cm2.
• Caviar-1 Well (located 128 Km northeast of area):
Pimienta Formation: 15.74 °API Oil; gas solubility at initial pressure relationship (Rsi),
33.28 m3/m3; Oil Volume Factor (Bo), 1.1659 m3/m3 and a saturation pressure (Pb)
of 106.16 Kg/cm2.
• Furbero-106 Well (located 64 Km southeast of area):
Tamán Formation: 37.11 °API Oil; gas solubility at initial pressure relationship (Rsi),
179.60 m3/m3; Oil Volume Factor (Bo), 1.8138 m3/m3 and a saturation pressure (Pb)
of 175.10 Kg/cm2.
• Soledad-101 Well (located within the block):
Tamabra Formation: 31.8 °API Oil; gas solubility at initial pressure relationship (Rsi)
of 163.42 m3/m3; Oil Volume Factor (Bo), 1.4997 m3/ and a saturation pressure
(Pb) of 224.28 Kg/cm2.
4
Basin Description
The Tampico - Misantla basin is located in Eastern Mexico and it spans from Southern
Tamaulipas to the Central part of the state of Veracruz, along with a small part of the East
side of the States of San Luis Potosí, Hidalgo and North of Puebla, down to the 200-m
isobaths of the Gulf of Mexico's continental shelf.
Location of Tampico – Misantla Basin
The crystalline basement is formed by igneous and metamorphic rock, their ages ranging
from Permian to the middle Jurassic. In the sedimentary column of the Tampico-Misantla
province, the following tectono-sequences are identified:
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First tectono-sequence (Synrift). Started in the Triassic (250Ma), with the deposition of
continental clasts from alluvial and fluvial environment with some lava flowed from the
Huizachal formation, from the late Triassic age (Noriense-Retiense), over crystalline and
metamorphic basements, later the Huayacocotla formation from the Lower Jurassic
(Hettangiano-Pliensbachiano) was deposited, and it is a sandstones and shale sequence,
from transgressive oceans. By the middle Jurassic, continental conditions were restored,
with Clasts from the Cahuasas formation being deposited, by the end of this period, a new
marine transgression commenced, and favored the deposition of oolithic limestone for
the Huehuetepec formation (Bathonian), and sandy limestone with bioclasts and ooliths
for the Tepexic formation (Callovian), which were overlain by calcareous and
carbonaceous shale with plenty of organic matter, from the Santiago formation
(Oxfordian), deposited on constrained, low-energy seas; as the marine transgression
moved forward, carbonate ramps developed around the basement highs - inside and on
the edge of the former, sandy-clayey limestone and oolithic limestone from the San Pedro
and San Andrés formations were deposited, (Kimmeridgian), respectively, and their lateral
equivalents toward deeper waters, namely, the clayey limestones with scarce bioclasts
and oolites (Chipoco formation) and basin black clayey limestones (Tamán formation).
The transgressive sea conditions continued so that during the Tithonian-Portlandian, a
maximum flooding surface would occur, with most of the basement highs being left in
underwater conditions. During that time, clayey-carbonaceous limestones were
deposited, (rich in organic matter) from the Pimienta formation, from a relatively-deepwater environment, which is present throughout the region and only in the parts
emerging from the basement, which were under coastal and/or shoreline conditions; La
Casita formation was deposited, which is constituted by glauconitic sandstones.
Passive Margin Tectono-sequence. The marine transgression carried on and ultimately
flooded all of the basement highs, it deposited on the internal parts, limestones and
dolomites, while on the edges, the organic-reefal growths development commenced. At
the same time, and due to the thermal subsidence, the lower areas deepened, giving rise
to deep sea basins, where the three members of the Tamaulipas Inferior formation were
deposited (calcarenithic member, bentonitic member and creamy limestone member)
corresponding to the Berriasian-Barremian age. During the Aptian stage, the Otates
horizon formation deposition occurred, which is considered to be a condensed sequence.
During the Albian, along the entire Tuxpan platform a reef edge, roughly 1400 m thick,
which gave rise to lagoon facies on the inside of the platform, whereas for the reef front,
the Tamabra formation, featuring proximal, mean and distal slope facies, developed due
6
to the reefal denudation, and changes facies with the chalky limestone Tamaulipas
Superior formation.
By the end of the Cenomanian, the platform remained under subaerial conditions by a
regressive marine pulse, which was followed by a new transgressive event allowing the
deposition both in lagoon facies and in the mean, distal slope and basin of the Turonian
Agua Nueva (black clayey limestones with black shales interbeddings), ConiacianSantonian San Felipe (greenish-grey clayey limestone with abundant olive green bentonite
interbeddings) and Campanian-Maastrichtian Méndez (clayey limestones and green/red
marls) formations; the period of this tectono-sequence ended with the deposition of the
last formation.
Eventos
Tectónicos
Ambientes
sedimentarios
Geologic column for the Tampico-Misantla basin with reservoir rock, source rock
(unconventional reservoirs), tectonic events and sedimentary environments
7
The foreland basin tectono-sequence is characterized by the onset of the Sierra Madre
Oriental's (SMO) uplift, which gave rise to a greater contribution of terrigenous material
sediments; these marine cenozoic depositions were originally defined as Tampico-Misantla
Basin by López-Ramos (1956).
The ongoing uplift of the SMO left very narrow coastal plains and continental shelves,
hence the coastal systems would go from a prodelta to a slope, and where the transport of
sediments by means of turbidity currents prevailed, there would be flow of debris and
landslides, which would produce deposition of submarine fans at the bottom of the
seafloor (basin), overlapping each other and generating submarine erosion during their
development.
By the end of the Cenozoic, deltaic environments prevailed.
Tuxpan
Poza Rica
Tecolutla
Tertiary Sedimentary model (Paleogene and Neogene). Note that delta environments
were deposited above the Chicontepec formation
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Main Features
The main producing formation is Chicontepec, having evidence of production in the
Méndez, Tamabra, Tamaulipas Superior and Tamán from the Upper, Medium Cretaceous
and Upper Jurassic, respectively.
The reservoirs in this Block are located in combined, structural (anticlines with subtle dips
with four-direction closure) and stratigraphic traps.
This block features 56 wells which reached down to the Mesozoic; of these wells, logs for
36 oil and gas producers are available, one from the Méndez formation with an initial rate
of 1,459 bpd, 32 from the Tamabra formation with initial rates ranging between 44 and
1,522 bpd, one in the Tamaulipas Superior formation with a rate of 223 bpd and two in the
Taman formation with initial rates of 2126 and 126 bpd, respectively. There are 16 wells
with gas and/or oil shows during drilling through the Méndez, San Felipe, Agua Nueva,
Tamabra, Tamaulipas Superior, Inferior and Tamán formations; likewise, 50 wells with
impregnations in cores and channel samples were reported in the Méndez, San Felipe,
Agua Nueva, Tamabra, Tamaulipas Superior, Tamaulipas Inferior, Pimienta and Tepexic
formations.
Examples of producing wells in the Mesozoic include: Guadalupe-2 from the Méndez
formation, Soledad-105 from the Tamabra formation, Coyotes-3 from the Tamaulipas
Superior formation and Guadalupe-1 from the Tamán formation.
In the Guadalupe-2 well, significant gas and oil shows were observed in the Méndez
formation - the well flowed mud, gas and oil during 5.25 hours. Four cores were cut at the
Tamán formation, exhibiting very poor light brown oil impregnation. Slightly viscous dark
black oil impregnations were observed In the channel samples from the Agua Nueva
formation, whilst regular light brown oil impregnations were observed in the Tamabra
formation.
One production test was performed in the 55-1765 m interval at the Méndez formation,
producing 1,459 bpd of oil, 1.8% water, GOR 90 m3/m3 through 13 mm production tubing
(TP, in Spanish).
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In the Soledad-105 well, no gas or oil shows were detected during drilling, no cores were
cut, and the channel samples from the Tamabra formation exhibit regular to good oil
impregnation; fracture with slight oil stains were observed in the Tamaulipas Superior and
Inferior Formations.
One production test was performed in the 1970-1981 m interval in the Tamabra formation,
it was treated with acid and flowed 1,522 bpd of oil, 3.4% water and GOR= 128 m3/m3
through 10 mm production tubing (TP, in Spanish).
In the Coyotes-3 well, no gas or oil shows were detected during drilling. Two cores were
cut in the Tamaulipas Inferior (1) and Pimienta (1) formations, exhibiting poor oil
impregnation. Slight oil impregnations were detected in the channel samples from the
Tamaulipas Superior and Inferior formations.
Three production tests with acid treatment were performed, in the Tamaulipas Superior
formation: the first test was performed in the 2139-2152 m interval, drilled and flowed
100% salt water; the second production test was performed in the 2043-2053 m interval about 50 - 80% of oil and 1 - 36% water flowed intermittently; a production of 223 bpd oil
was reported, 36% water and GOR 250 m3/m3 - the interval was plugged later on. The
third production test at the 2043-2046 m interval, water with a small amount of oil flowed,
and the test was completed, deeming the section flooded with salt water.
In the Guadalupe-1 well, gas shows were observed in the Tamán formation, high gas
readings in mud, GL from 230 to 180. 12 cores exhibit light to regular oil impregnation in
the Agua Nueva Basal, Tamabra, Tamaulipas Inferior, Pimienta, Tamán and Tepexic
formations. Oil impregnations were observed in the channel samples for the Agua Nueva
Basal, Tamaulipas Inferior, Pimienta and Tamán formations with regular oil spots.
Two production tests with acid treatment were performed in the Tamán formation, first in
the 2941-2949 m interval, flowing 2,126 bpd of oil, 1.8% water, GOR 286 m3/m3; the
second test was performed in the 2923-2928 m interval; a sample was taken whilst flowing
to the battery: 60 - 70% water, pH: 5 - 6.
Comments concerning the events during the drilling through the Chicontepec formation
rocks are provided below:
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492 wells are located in the Soledad block, 468 produced from the Chicontepec formation
at rates between 10 and 509 bpd, with a cumulative production between 10,258 and
497,732 bls, with an average per well of 96,756 bls, evidencing the attractiveness of this
formation.
Relevant events during the drilling of the Chicontepec formation include slight to
moderate gas shows and oil impregnations observed in cores and channel samples, which
were regular to light in the area. Below is a summary of four wells which produced from
this formation.
In the Soledad-118 well, no gas or oil shows were detected during drilling, no
impregnations were observed in the channel samples either.
One production test was performed in the Chicontepec Medio formation in the 1040-1115
m and 1125-1210 m intervals; hydraulic fracturing was performed, yielding a production of
509 bpd oil with 0% water.
In the Soledad Norte-118 well, during drilling through the Chicontepec Medio formation at
1,350 m, moderate gas flow occurred and slight oil, impregnations were observed in the
cores cut at the Chicontepec Medio formation; no impregnations were observed in the
channel samples.
One production test was conducted in the Chicontepec Medio formation at the 1042-1062
m interval; hydraulic fracturing was performed, reporting a production of 308 bpd oil, 0%
water and GOR: 67 m3/m3.
In the Soledad Norte-358 well, no gas or oil shows were detected during the drilling, whilst
slight, viscous oil impregnations were observed in the channel samples at the Chicontepec
Medio formation
One production test was performed in the Chicontepec Medio formation, 1160-1190 m
interval; hydraulic fracturing was performed, reporting a production of 302 bpd oil and 0%
water.
In the Soledad Norte-133 well, no gas or oil shows were detected during the drilling, no oil
impregnations were observed, either.
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One production test was performed in the Chicontepec Medio formation, 1180-1255 m
interval; hydraulic fracturing was performed, reporting a production of 296 bpd oil, 0%
water, GOR: 100 m3/m3.
The wells' geophysical logs were used to produce correlation structural sections; the
seismic information was also used to correlate the Mesozoic formations' distinctive events.
The figure shown below is a correlation section with a W-E orientation - notice the
structural correlation between the Ahuatepec-1, Soledad Norte-94, 187, 284 and 269,
highlighting the fine development of the Chicontepec formation's producing sands, and
that the Ahuatepec-1 well reached the Upper Jurassic formations, where the hydrocarbon
source rocks are, currently considered to be unconventional reservoirs or Oil Shale.
E
W
Ahuatepec-1
Sección III
BLOQUE_SOLEDAD_S3
Soledad Nte-94
E
BLOQUE_SOLED
Soledad Nte-187 Soledad Nte-284 Soledad Nte-269
Terciar
io
BLOQUE SOLEDAD
SECCION III
Ahuatepec 1
Soledad Norte 94
Soledad Norte 187
Soledad Norte 284
Soledad Norte 269
BLOQUE SOLED
SECCION II
Ahuatepec
Soledad Norte
Soledad Norte
Soledad Norte
Soledad Norte
Cretácico
W
Jurásico
E
W-E Structural cross section with well logs. Notice the presence of Jurassic rocks in the
Ahuatepec-1 well.
12
The following figure shows the same section with seismic information, which shows
attractive Mesozoic rock thicknesses, and evidencing the well-developed Upper Jurassic
formations which are present in the Ahuatepec-1 well.
AHUAT-1
SON-94
SON-269
SON-187
BLOQUE SOLEDAD
SECCION III
Ahuatepec 1
Soledad Norte 94
Soledad Norte 187
Soledad Norte 284
Soledad Norte 269
N
Seismic cross section, identical to the wells correlation where the presence of Jurassic
source rocks in the Ahuatepec-1 well can be observed.
The Soledad block is located on the north side of the Chicontepec Paleochannel, there is
3D seismic data for 100% of this area, derived from the Amatitlán prospect processed on
2009, and on the south from Cohuca, processed on 2011, and on the Southeast from
Miquetla-Miahuapan, processed on respectively. According to the seismic archives, these
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seismic cubes feature pre-stacking time migration, with good quality and optimal vertical
resolution; however, edge effects are present on the boundaries of the seismic cubes,
giving rise to decouplings when two seismic cubes from two different projects are laid side
by side.
In addition, 50 km of bidimensional (2D), 28-seismic segments are available inside the
Soledad block.
The Soledad block features 100% coverage of 3D seismic information from the
Amatitlán, Miquetla-Miahuapan and Cohuca prospects.
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Exploration and Development History
The Soledad block was discovered in September 1944 upon drilling the Soledad-1 well,
which produced 44 bpd from the Tamabra formation, the well was abandoned as non
commercial producer. The first well producer from this area is Soledad-101, drilled in
1961, with a rate of 1,082 bpd, 0% water, from the Tamabra formation; later on, the
Soledad-104 well produced at a rate of 547 bpd and a fractional water flow of 2.6%
from the same formation.
The maximum production reached was 7,244 bpd, with 133 active wells in April,
1980.
In 2010, operation and maintenance activities resumed, reactivating wells with minor
workovers in the Coyotes and Horcones fields, which are East of this Block; it is worth
mentioning that the average well rates prior to reactivation (April 2010) were 20 bpd,
from 79 wells in operation, averaging 1750 bpd a month, whilst currently (July 2012), the
average rate is 30 bpd with 110 wells in operation and an average monthly production of
3300 bpd.
Drilling activity restarted in 2011 and 2012: three horizontal wells were drilled, and to this
day, two have been completed: Coyotes 423D and Coyotes 276D, both completed with
multifraccing (five) and the initial rate for the first one was 400 bpd of 37°API net oil and
0.471 mmmpcd with 30% water cut, which dropped to 15% later on; the initial rate for the
second well was 318 bpd of 28°API oil and 0.093 mmmpcd of gas and 35% water cut,
currently undergoing swabbing, hence the water cut is expected to drop as in the first
well.
15
Structural seismic section for Coyotes 423D well with horizontal trajectory.
RESU
RE
Geométricos
Geométrico
Geométric
Longitud Total
Longitud
Longitudtota
to
Xf
XfXf
Altura (H)
Altura
Altura(H)(H
Network
Network
Network
Dirección
Dirección
Dirección
Arena
Ottawa
20/40
ArenaOtaw
Ota
Arena
20/40
20/40
Fluido
de Fractura
Fluido
Frac
Fluido Fractu
Coyotes 423 wellbore schematic and geophysical log with the surveyed interval in which
five fractures were performed.
16
Currently, Petróleos Mexicanos has initiated an exploration campaign for the assessment
of geological formations considered to be source rocks, i.e., shale oil, by means of
horizontal wells drilling; the drilling of one exploration well 1.4 km away from this block is
under consideration, its main objective being the Upper Jurassic's Pimienta formation.
0
500
1000
KS Mendez
KS SF
KS ANva
KM Tam Sup
KI Tam Inf
1500
JS Tithoniano
JS Kimmeridgiano
2000
2500
3000
3500
SE
NW
Configuración
estructural cima Fm.
Pimienta (m)
Exploration location for the assessment of the Pimienta formation from Upper Jurassic
17
Production by Field and Reserves
The commercial exploitation of oil in this block commenced in 1972 and the production is
associated to the Soledad field reservoir.
The maximum production reached was 7,244 bpd in April, 1980, with 133 active wells
from the Tertiary formations (Chicontepec).
The saturation pressure ranges between 84 to 97 Kg/cm2 and the current pressure ranges
between 58 and 125 Kg/cm2.
8,000
1,400
1,200
6,000
1,000
5,000
800
4,000
600
3,000
Gastos de gas (mpc/d)
Gastos de aceite, agua (b/d)
7,000
400
2,000
200
1,000
Aceite (Bd)
Agua (Bd)
06/06
07/05
08/04
09/03
10/02
11/01
12/00
01/00
02/99
03/98
04/97
05/96
06/95
07/94
08/93
09/92
10/91
11/90
12/89
01/89
02/88
03/87
04/86
05/85
06/84
07/83
08/82
09/81
10/80
11/79
12/78
01/78
02/77
03/76
04/75
05/74
06/73
07/72
08/71
09/70
10/69
11/68
12/67
01/67
0
02/66
0
Gas (mpc/d)
Production history from contractual area Soledad
The original oil in place for the block is 1,709.062 MMbl of oil and 1,208.686 MMMpc of
gas; the cumulative production is 39 MMbl of oil and 5.7 MMMpc of gas, with a recovery
factor of 8.0 % for oil and 56.0 % for gas. The estimated 29 remaining reserves are
estimated in 85.780 MMbl oil and 201.057 MMMpc gas.
Área
desarrollada
por campo
(Km2)
125
Volumen
original
Aceite
(MMbl)
Gas
(MMMpc)
1,709.062 1,208.686
Factores de
recuperación
Producción
acumulada
Reservas
remanentes 2P
Aceite
(%)
Gas
(%)
Aceite
Gas
(MMbl) (MMMpc)
Aceite
(MMbl)
Gas
(MMMpc)
8.0
56.0
39.00
85.780
201.057
5.70
Original oil in place, production and remaining reserves from contractual area Soledad
18
Infrastructure and Hydrocarbons Management
Infrastructure in Soledad block
The Soledad block has a gross production of 4,158 bpd, which is processed in the
Soledad I, Soledad II and Palo Blanco separation batteries; from that point, the gas
is transported by a 12” x 2.6 km pipeline, starting in the Soledad I separation
battery, where it is processed and then sent to EC Soledad; it is subsequently sent
to CPG PR. The oil is sent through a 8” pipeline to the Miquetla I separation battery
which leads up to CAB-PR. The Palo Blanco separation battery sends the gas
through a 16” pipeline to EC Soledad and the oil is transported through a 4”
pipeline which starts in BS Soledad I and leads up to CAB-PR.
Production handling for Soledad block
19
The block is fitted with the pipelines described below:
20
Roads within the Soledad block
Road map (roads and unpaved roads) villages, well pads and oil facilities
21
Drilling History
Drill parameters
Depth: 1,600 meters developed
Deviations: 0° to 45°
Mud density
First stage: 1.15 gr/cm³; bentonite mud
Second stage: 1.26 gr/cm³; inverse emulsion
Third stage: 1.30 gr/cm³; inverse emulsion
Objective:
Chicontepec
Difficulties during drilling
Surface stage
Hydration of clays, circulation losses, drag during lowering of casings, borehole instability
and shallow Gas and/or Water flows.
Intermediate stage.
Reactive shale interbeddings, pipes getting stuck and possible fluid loss, high penetration
speeds, possible increases in equivalent circulating density (DEC, in Spanish) due to
concentration of cuttings in the annulus and increases in the number of jamming and
circulation losses.
Production stage
Packing, resistance and drag, presence of formation gas, circulation losses, jamming due
to differential pressure, bit balling, accumulation of slag in the curved section.
Drill practices
Most of the casing piping (TR, in Spanish) setups in this area correspond to one of two
different designs:
The first design is a 10 3/4" conductor casing, which is intended for the installation of
surface tie-ins and is cemented down to around 50 to 150 m. The 7 5/8" intermediate
casing is cemented at average depths between 400 and 500 m, the setting depth for that
22
stage is proposed based on the correlation wells. Finally, the third stage is drilled and
fitted with a 5 1/2" casing which is cemented down to the total depth.
The second design comprises a 9 5/8" conductor casing, intended for the installation of
surface tie-ins and is cemented down to around 50 and 150 m. The final 6 5/8" casing is
cemented down to 1,500 to 1,700 m.
The objective of this section is to review common drilling practices used in the
development of this reservoir; they are listed as a reference and not as a proposed
application of methodology and technology by AIATG.
The first stages are at normal pressure, and are drilled with water-based mud and with
control densities ranging between 1.15 to 1.30 gr/cm3; in the case of abnormal densities,
this is due to the shale stability control and not because it is required by the pressure
gradient. The exploitation stage is drilled with water-based fluid (sodium brine), capable
of increasing its viscosity in case of any contingency; it is also friendly to the production
formation, and the control density can be adjusted.
The Christmas tree dimensions are 10 3/4” x 7 5/8” x 5 1/2” x 2 7/8” 5,000 lb/pg².
No problems were encountered during the drilling process.
23
24
25
26
***
27

Integrated Contract EP: Soledad

Transcription

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