logging


TERMINOLOGY
Like most professions, petroleum engineering is beset with jargon.
Therefore, it will make things simpler if I first go through some of the
basic terms that will be used throughout this book. Petroleum engineering
is principally concerned with building static and dynamic models of
oil and gas reservoirs.
Static models are concerned with characterizing and quantifying the
structure prior to any production from the field. Hence, key parameters
that the models aim to determine are:
STOIIP = stock tank oil initially in place; usually measured in stock
tank barrels (stb)
GIIP = gas initially in place; usually measured in billion standard cubic
feet (Bcf)
GBV = gross bulk volume; the total rock volume of the reservoir
containing hydrocarbon
NPV = net pore volume; the porespace of the reservoir
HCPV = hydrocarbon pore volume; the porespace actually containing
hydrocarbon
f = porosity; the proportion of the formation that contains fluids
k = permeability; usually expressed in millidarcies (md)
Sw = water saturation; the proportion of the porosity that contains water
Sh = hydrocarbon saturation; the proportion of the porosity that contains
hydrocarbon
FWL = free water level; the depth at which the capillary pressure in the
reservoir is zero; effectively the depth below which no producible
hydrocarbons will be found


HWC = hydrocarbon/water contact; the depth below which the formation
is water bearing as encountered in a particular well. Likewise,
OWC for oil and GWC for gas
GOC = gas oil contact; the depth below which any gas in the reservoir
will be dissolved in the oil
Gross thickness = the total thickness of the formation as encountered
in a particular well
Net thickness = the part of the gross thickness that contains porous rock
subject to given cutoff criteria
Pay thickness = the part of the net thickness that is considered to be
capable of producing hydrocarbons in a particular well
Because of inherent uncertainties in all the parameters used to determine
STOIIP or GIIP, geologists will usually develop probabilistic
models, in which all the parameters are allowed to vary according to distribution
functions between low, expected, and high values. The resulting
static models may then be analyzed statistically to generate the following
values, which are used for subsequent economic analyses:
P50 STOIIP: the value of the STOIIP for which there is a 50% chance
that the true value lies either above or below the value
P15 STOIIP: the value of the STOIIP for which there is only a 15%
chance that the true value exceeds the value. Often called the high case.
P85 STOIIP: the value of the STOIIP for which there is an 85% chance
that the true value exceeds the value. Often called the low case.
Expected STOIIP: the value of the STOIIP derived by taking the
integral of the probability density function for the STOIIP times the
STOIIP. For a symmetric distribution, this will equal the P50 value.
Similar terminology applies to GIIP.
In order to predict the hydrocarbons that may be actually produced from
a field (the reserves), it is necessary to construct a dynamic model of the
field. This will generate production profiles for individual wells, subject
to various production scenarios. Additional terminology that comes into
play includes:
Reserves = the part of the STOIIP or GIIP that may be actually produced
for a given development scenario. Oil companies have their own
rules for how reserves are categorized depending on the extent to which
they are regarded as proven and accessible through wells. Terms fre-
2 Well Logging and Formation Evaluation

quently used are proven reserves, developed reserves, scope for recovery
reserves, probable reserves, and possible reserves.
Remaining reserves = that part of the reserves that has not yet been
produced
Cumulative production = that part of the reserves that has already been
produced
UR = ultimate recovery; the total volume of reserves that will be produced
prior to abandonment of the field
NPV = net present value; the future economic value of the field, taking
into account all future present value costs and revenues
RF = recovery factor; the reserves as a proportion of the STOIIP
(or GIIP)
Bo = oil volume factor; the factor used to convert reservoir volumes of
oil to surface (stock tank) conditions. Likewise Bg for gas.
In order to produce the hydrocarbons, wells are needed and a development
strategy needs to be constructed. This strategy will typically be presented
in a document called the field development plan (FDP), which
contains a summary of current knowledge about the field and the plans
for future development.
Once an FDP has been approved, the drilling campaign will consist of
well proposals, in which the costs, well trajectory, geological prognosis,
and data-gathering requirements are specified. The petrophysicist plays a
part in the preparation of the well proposal in specifying which logs need
to be acquired in the various hole sections.

lecture (5) Drilling Tools & Deflection Methods


Drilling Tools & Deflection Methods
About this chapter
Before the arrival of the positive-displacement mud motor (PDM), whip-stocks, knuckle
joints and jetting (in soft formations) were used as deflection methods. DD tools and
technology have evolved tremendously in the past 20 years. Today, there is a broad range
of PDMs for different applications.
The various methods used to deflect a wellbore are described in this chapter. Orientation
is covered separately in Chapter 11. The DD must be familiar with all the DD tools at the
rig-site and in the workshop. EQ Jars and PDMs are covered separately in this manual.
The remaining DD tools are briefly described here. More detailed information is
available from the manufacturers. Most of the DD tools are straightforward to operate.
While a directional drilling simulator is a useful aid in the teaching of DD concepts, the
only way to fully understand how a wellbore is deflected and how the various DD tools
are used is to get some on-the-job training. This chapter should provide a lot of the
background knowledge required.
Objectives of this Chapter
On completing this chapter the directional driller should be able to do the following
exercises
1. Describe the use of an open-hole whip-stock.
2. Explain how deflection is achieved using the jetting kickoff technique.
3. Explain what determines the dogleg severity achieved with a non-steerable PDM
kickoff BHA.
4. Describe the uses and applications of:
DC, SDC, NMDC, SNMDC, I.B. stabilizer, Sleeve-type stabilizer(s), clamp-on
stabilizer, RWP, Bent Sub, UBHO, BOS, Underreamer, String Reamer, Bullnose,
Hole Opener, Key-seat Wiper, Section Mill, Shock Sub, Rebel Tool.
5.1 Drilling Tools
The major drilling tools likely to be used by the DD are discussed briefly here. For more
detailed information on a particular tool, it is necessary to refer to the "Composite
Catalog" or to the manufacturer’s data sheets.
5.1.1 Drill Collar (DC)
Drill collars are heavy, stiff steel tubulars. They are used at the bottom of a BHA to
provide weight on bit and rigidity. Flush or spiral drill collars are available. In directional
drilling, spiral drill collars are preferable (Figure 5-1). The spiral grooves machined in
the collar reduce the wall contact area by 40% for a reduction in weight of only 4%. The
chances of differential sticking are greatly reduced. Spiral drill collars usually have slip
and elevator recesses. Stress-relief groove pins and bore back boxes are optional. The
drill collars (various sizes) are normally owned by the drilling contractor.



5.1.1.1 Short Drill Collar (SDC)
Often called a pony collar, this is simply a shortened version of a steel drill collar. Short
drill collars may be manufactured or a steel drill collar may be cut to make two or more
short collars. For the DD, the SDC and the short non-magnetic drill collar (SNMDC)
have their widest application in the make-up of locked BHAs. SDCs of various lengths
(e.g. 5’, 10’, 15’) are normally provided by the DD company.
5.1.1.2 Non-Magnetic Drill Collar (NMDC)
Non-magnetic drill collars are usually flush (non-spiral). They are manufactured from
high-quality, corrosion-resistant, austenitic stainless steel. Magnetic survey instruments
run in the hole need to be located in a non-magnetic drill collar of sufficient length to
allow the measurement of the earth’s magnetic field without magnetic interference.
Survey instruments are isolated from magnetic disturbance caused by steel components
in the BHA and drillpipe. ANADRILL’s M1 MWD tool and its successors are fixed
inside their own special MWD non-magnetic drill collars. SLIM-1, however, is run
inside a standard NMDC. Stress-relief groove pins and bore back boxes are optional.
5.1.1.3 Short Non-Magnetic Drill Collar (SNMDC)
A short version of the NMDC, SNMDCs are often made by cutting a full-length NMDC.
The SNMDC may be used between a mud motor and an MWD collar to counteract
magnetic interference from below. It is also used in locked BHAs, particularly where the
borehole's inclination and direction give rise to high magnetic interference. Finally,
BHAs for horizontal wells often use a SNMDC.
5.1.2 Float Sub
This is a PIN x BOX sub which is bored out to take a float valve. It is often run above a
mud motor. In conventional rotary BHAs, a float valve is inserted either in the bit sub (in
the case of a pendulum BHA) or in the bored-out near-bit stabilizer. Poppet and flapper
designs of float valve are available. Note that some clients may not allow the use of a
float valve (because of kick-control problems). The DD should check the client's
regulations on arrival at the rig. The float sub is usually provided by the DD company.
The float valve is usually provided by the drilling contractor.

5.1.3 Bit Sub
This is a BOX x BOX sub which is run directly above the bit (hence its name) when no
near-bit stabilizer is used. It is bored out to take a float valve. Various sizes of bit sub are
normally provided by the drilling contractor.
5.1.4 Junk Sub
A junk sub is fabricated from a solid steel body with a necked-down mid-portion. A
"skirt" is fitted to the lower part of the body, around the necked-down portion, forming a
basket for junk to settle in (Figure 5-2).
The junk sub is run directly above the bit. It catches pieces of junk which are too heavy
to circulate out. Bleed holes in the skirt allow the mud to return to the system. The junk
sub is provided by the drilling contractor.





5.1.5 Extension Sub
This is a short sub which can be used to fine-tune a BHA. It is normally PIN x BOX. A
float sub can be used as an extension sub. The extension sub is usually provided by the
DD company.
5.1.6 Heavyweight Drill Pipe (HWDP)
This is an intermediate-weight drill string member with drill pipe dimensions for easier
handling. Its heavy wall tube is attached to special extra-length tool joints. These provide
ample space for recutting the connections and reduce the rate of wear on the OD. The
OD of the tube is also protected from abrasive wear by a centre wear pad (Figure 5-3).
Tool joints and wear pad are hard-banded. Some HWDP have two wear pads.



HWDP is less rigid than DCs and has much less wall contact. Chances of differential
sticking are reduced. Its three-point wall contact feature solves two serious problems in
directional drilling. It permits high-RPM drilling with reduced torque. HWDP can be run
through hole angle and direction changes with less connection and fatigue problems.
Today, the trend in BHA design is to minimize the number of DCs in the BHA and use
HWDP to comprise a major portion of available weight on bit
HWDP is normally provided by the drilling contractor. However, it is the DD’s
responsibility to ensure there are sufficient joints of HWDP on the rig. For normal
directional jobs, 30 joints of HWDP should be sufficient.

Corrosion (1)

Corrosion is the destructive attack of a material by reaction with its
environment. The serious consequences of the corrosion process have
become a problem of worldwide significance. In addition to our everyday
encounters with this form of degradation, corrosion causes plant
shutdowns, waste of valuable resources, loss or contamination of product,
reduction in efficiency, costly maintenance, and expensive overdesign;
it also jeopardizes safety and inhibits technological progress.
The multidisciplinary aspect of corrosion problems combined with the
distributed responsibilities associated with such problems only
increase the complexity of the subject. Corrosion control is achieved by
recognizing and understanding corrosion mechanisms, by using corrosion-
resistant materials and designs, and by using protective systems,
devices, and treatments. Major corporations, industries, and government
agencies have established groups and committees to look after
corrosion-related issues, but in many cases the responsibilities are
spread between the manufacturers or producers of systems and their
users. Such a situation can easily breed negligence and be quite costly
in terms of dollars and human lives.
I.1 The Cost of Corrosion
Although the costs attributed to corrosion damages of all kinds have
been estimated to be of the order of 3 to 5 percent of industrialized
countries’ gross national product (GNP), the responsibilities associated
with these problems are sometimes quite diffuse. Since the first significant
report by Uhlig1 in 1949 that the cost of corrosion to nations
is indeed great, the conclusion of all subsequent studies has been that
corrosion represents a constant charge to a nation’s GNP.2 One conclusion
of the 1971 UK government-sponsored report chaired by Hoar3
was that a good fraction of corrosion failures were avoidable and that
improved education was a good way of tackling corrosion avoidance.

Corrosion of metals cost the U.S. economy almost $300 billion per
year at 1995 prices.4 Broader application of corrosion-resistant materials
and the application of the best corrosion-related technical practices
could reduce approximately one-third of these costs. These
estimates result from a recent update by Battelle scientists of an earlier
study reported in 1978.5 The initial work, based upon an elaborate
model of more than 130 economic sectors, had revealed that metallic
corrosion cost the United States $82 billion in 1975, or 4.9 percent of
its GNP. It was also found that 60 percent of that cost was unavoidable.
The remaining $33 billion (40 percent) was said to be “avoidable”
and incurred by failure to use the best practices then known.
In the original Battelle study, almost 40 percent of 1975 metallic corrosion
costs were attributed to the production, use, and maintenance
of motor vehicles. No other sector accounted for as much as 4 percent
of the total, and most sectors contributed less than 1 percent. The 1995
Battelle study indicated that the motor vehicles sector probably had
made the greatest anticorrosion effort of any single industry. Advances
have been made in the use of stainless steels, coated metals, and more
protective finishes. Moreover, several substitutions of materials made
primarily for reasons of weight reduction have also reduced corrosion.
Also, the panel estimated that 15 percent of previously unavoidable
corrosion costs can be reclassified as avoidable. The industry is estimated
to have eliminated some 35 percent of its “avoidable” corrosion
by its improved practices. Table I.1 summarizes the costs attributed to
metallic corrosion in the United States in these two studies.




I.2 Examples of Catastrophic
Corrosion Damage
I.2.1 Sewer explosion, Mexico
An example of corrosion damages with shared responsibilities was the
sewer explosion that killed over 200 people in Guadalajara, Mexico, in
April 1992.6 Besides the fatalities, the series of blasts damaged 1600
buildings and injured 1500 people. Damage costs were estimated at 75
million U.S. dollars. The sewer explosion was traced to the installation
of a water pipe by a contractor several years before the explosion that
leaked water on a gasoline line laying underneath. The subsequent
corrosion of the gasoline pipeline, in turn, caused leakage of gasoline
into the sewers. The Mexican attorney general sought negligent homicide
charges against four officials of Pemex, the government-owned oil
company. Also cited were three representatives of the regional sewer
system and the city’s mayor.
I.2.2 Loss of USAF F16 fighter aircraft
This example illustrates a case that has recently created problems in
the fleet of USAF F16 fighter aircraft. Graphite-containing grease is a
very common lubricant because graphite is readily available from steel
industries. The alternative, a formulation containing molybdenum
disulphide, is much more expensive. Unfortunately, graphite grease is
well known to cause galvanically induced corrosion in bimetallic couples.
In a fleet of over 3000 F16 USAF single-engine fighter aircraft,
graphite grease was used by a contractor despite a general order from
the Air Force banning its use in aircraft.7 As the flaps were operated,
lubricant was extruded into a part of the aircraft where control of the
fuel line shutoff valve was by means of electrical connectors made from
a combination of gold- and tin-plated steel pins. In many instances corrosion
occurred between these metals and caused loss of control of the
valve, which shut off fuel to the engine in midflight. At least seven aircraft
are believed to have been lost in this way, besides a multitude of
other near accidents and enormous additional maintenance.
I.2.3 The Aloha aircraft incident
The structural failure on April 28, 1988, of a 19-year-old Boeing 737,
operated by Aloha airlines, was a defining event in creating awareness
of aging aircraft in both the public domain and in the aviation community.
This aircraft lost a major portion of the upper fuselage near the
front of the plane in full flight at 24,000 ft.8 Miraculously, the pilot managed
to land the plane on the island of Maui, Hawaii. One flight attendant
was swept to her death. Multiple fatigue cracks were detected

in the remaining aircraft structure, in the holes of the upper row of rivets
in several fuselage skin lap joints. Lap joints join large panels of
skin together and run longitudinally along the fuselage. Fatigue cracking
was not anticipated to be a problem, provided the overlapping panels
remained strongly bonded together. Inspection of other similar
aircraft revealed disbonding, corrosion, and cracking problems in the
lap joints. Corrosion processes and the subsequent buildup of voluminous
corrosion products inside the lap joints, lead to “pillowing,” whereby
the faying surfaces are separated. Special instrumentation has been
developed to detect this dangerous condition. The aging aircraft problem
will not go away, even if airlines were to order unprecedented numbers
of new aircraft. Older planes are seldom scrapped, and the older
planes that are replaced by some operators will probably end up in service
with another operator. Therefore, safety issues regarding aging
aircraft need to be well understood, and safety programs need to be
applied on a consistent and rigorous basis.
I.2.4 The MV KIRKI
Another example of major losses to corrosion that could have been prevented
and that was brought to public attention on numerous occasions
since the 1960s is related to the design, construction, and
operating practices of bulk carriers. In 1991 over 44 large bulk carriers
were either lost or critically damaged and over 120 seamen lost
their lives.9 A highly visible case was the MV KIRKI, built in Spain in
1969 to Danish designs. In 1990, while operating off the coast of
Australia, the complete bow section became detached from the vessel.
Miraculously, no lives were lost, there was little pollution, and the vessel
was salvaged. Throughout this period it seems to have been common
practice to use neither coatings nor cathodic protection inside
ballast tanks. Not surprisingly therefore, evidence was produced that
serious corrosion had greatly reduced the thickness of the plate and
that this, combined with poor design to fatigue loading, were the primary
cause of the failure. The case led to an Australian Government
report called “Ships of Shame.” MV KIRKI is not an isolated case.
There have been many others involving large catastrophic failures,
although in many cases there is little or no hard evidence when the
ships go to the bottom.
I.2.5 Corrosion of the infrastructure
One of the most evident modern corrosion disasters is the present state
of degradation of the North American infrastructure, particularly in
the snow belt where the use of road deicing salts rose from 0.6M ton in
1950 to 10.5M tons in 1988. The structural integrity of thousands of

bridges, roadbeds, overpasses, and other concrete structures has been
impaired by corrosion, urgently requiring expensive repairs to ensure
public safety. A report by the New York Department of Transport has
stated that, by 2010, 95 percent of all New York bridges would be deficient
if maintenance remained at the same level as it was in 1981.
Rehabilitation of such bridges has become an important engineering
practice.10 But the problems of corroding reinforced concrete extend
much beyond the transportation infrastructure. A survey of collapsed
buildings during the 1974 to 1978 period in England showed that the
immediate cause of failure of at least eight structures, which were 12
to 40 years old, was corrosion of reinforcing or prestressing steel.
Deterioration of parking garages has become a major concern in
Canada. Of the 215 garages surveyed recently, almost all suffered varying
degrees of deterioration due to reinforcement corrosion, which was
a result of design and construction practices that fell short of those
required by the environment. It is also stated that almost all garages
in Canada built until very recently by conventional methods will
require rehabilitation at a cost to exceed $3 billion. The problem surely
extends to the northern United States. In New York, for example, the
seriousness of the corrosion problem of parking garages was revealed
dramatically during the investigation that followed the bomb attack on
the underground parking garage of the World Trade Center.