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8/10/2019 9002010 - Well info
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Integ
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In the Tamaulipas Superior formation, one production test was conducted in the 2315-
2335 m interval, flowing oil, gas and water; the analyses of samples indicate 18% water
with a salinity of 97500 ppm and pH = 5; these analyses show that the water is acid, thus
coming from the treatment performed on the well, therefore deducing a lack of evaluation
for this interval. The well was plugged as it was deemed non-producing.
The performance per producing unit of the Chicontepec formation will be discussed next.
In the Humapa contracted area, 42 wells are present, out of which 40 were assessed in the
Chicontepec formation; relevant events which occurred during drilling, and which were
detected in 10 wells, low to moderate gasification were encountered, lasting between 10
to 130 minutes; oil impregnations were observed in the cut cores and channel samples.
Chicontepec Superior Canal formation: during the drilling of this producing unit, slight to
moderate gas shows were observed in six wells (Coyol-461, Coyol-5231, Coyol-6076,
Humapa-517, Humapa-537 and Humapa-1024). Regular to light oil impregnations were
observed in cores and cuttings in seven wells (Barita-1, Chorlo-1, Coyol-6074, Coyol-6076,
Humapa-537, Humapa-1074 and Silvita-1).
Production tests were conducted in 33 wells, 28 of which became producers, with their
productions ranging between 10 to 384 bpd, which evidences the attractiveness of this
producing unit. Next is a review of the observations in the producing wells in this member.
In the Humapa-1458 well, no gas shows were observed in the mud while drilling. No cores
were cut and no impregnations in the channel samples were observed.
One production test was conducted in the upper member of the Chicontepec formation,
which turned out to be an oil producer, with an initial rate (Qoi) of 384 bpd, 0% water and
226 m3/m
3 GOR; the well was deemed an oil producer.
Chicontepec Medio Formation: During the drilling of this producing unit, light to moderate
gas shows were observed in two wells (Coyol-461 and Chorlo-1). Regular to light oil
impregnations were observed in cores and channel samples in six wells (Barita-1, Bornita-
1, Humapa-1D, Palmar-1, Chorlo-1 and Silvita-1).
Production tests were conducted in eight wells, six were producers; their production
ranged between 10 and 226 bpd, evidencing the attractiveness of this production unit. The
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11
following paragraphs present a review of the findings in one well which became a
producer in this member.
In the Bornita-1 well, no gas shows were observed in the mud while drilling. No cores were
cut and no impregnations were observed in the channel samples.
One production test was conducted in the Chicontepec medio formation member, with an
initial rate (Qoi) of 226 bpd; the well was deemed an oil producer.
Chicontepec Inferior Formation: During drilling of this producing unit, light to moderate
gas shows were observed in four wells (Coyol-461, Chorlo-1, Coyol-6058 and Coyol-6096).
Regular to light oil impregnations were observed in cores and cuttings in six wells (Barita-1,
Palmar-1, Chorlo-1, Coyol-6076, Humapa-527 and Silvita-1).
Production tests were conducted in four wells, two were producers, producing in a range
of 63 to 129 bpd, evidencing the attractiveness of this production unit. Next is a review of
the findings in one producing well in this member.
In the Coyol-6058 well, no gas shows in the mud where observed while drilling. No cores
were cut and no impregnations were observed in channel samples.
One production test was conducted in the Chicontepec formation member, with an initial
rate (Qoi) of 129 bpd, 0% water, 286 m3/m3 GOR, the well was deemed an oil producer.
The well geophysical logs were used to produce correlation structural sections; also, the
seismic data was used to correlate de Mesozoic formations' distinctive seismic events. The
figure below illustrates a correlation section with a NW - SE orientation, which sheds light
onto the structural correlation between the Palmar-1, Humapa-1044, Bornita-1 and
Humapa-2073 wells - notice the development of the producing sands of the Chicontepec
formation (Tertiary) in the Humapa-1044 and Bornita-1 wells; also notice that the Palmar-1
well also went through the Upper Jurassic formations, where the hydrocarbon source rocks
are located, currently considered unconventional reservoirs, also known as Oil Shale.
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Integrated
15
Exploration and Development History
The Humapa block was discovered in March, 1956 upon drilling the Humapa-1 well,
which was evaluated in the Chicontepec Medio and Inferior formations; during one
formation test, viscous mud was recovered and the well was plugged, deemed non-
producing. The first producing well in the block was Bornita-1, drilled in April 1977,
with a rate of 189 bpd, 0% water and GOR 100 m3/m
3 from the Chicontepec Medio
formation; the Humapa-1D well, drilled later in September 1977 through the
Chicontepec Medio formation produced at a rate of 57 bpd, 0% water and GOR 100
m3/m
3.
In 2010, the operation and maintenance activities were resumed; minor repairs were
conducted to reactivate wells on the Coyotes and Horcones fields, which are on the East
of this block; it is worth mentioning that the average rates of wells prior to reactivation
(April 2010) were 20 bpd for 79 operating wells, averaging 1750 bpd a month; currently
(July 2012), the average rate is 30 bpd for 110 operating wells and an average monthly
production of 3300 bpd.
Drilling activity resumed in 2011 and 2012; three horizontal wells were drilled - two have
been completed to this day: Coyotes 423D and Coyotes 276D, both completed withmultifraccing (five) and the initial rate for the former was 400 bod net oil @ 37°API and
0.471 mmmcfd and 30% water cut, which dropped to 15%; the initial rate for the second
well was 318 bod of oil @28 °API and 0.093 mmcfd of gas and 35% water cut; it is still
undergoing swabbing, therefore the water cut is expected to decrease, as observed in the
first well.