TYPES OF HEALTH INSURANCE


There are three types of health insurance: Disability income, Accidental Death and Dismemberment, and Medical Expense Insurance.

DISABILITY INCOME INSURANCE

Disability income insurance provides periodic payments when the insured is unable to work because of injury or sickness.  These policies provide a weekly or monthly income benefit to replace a portion of the salary or wages lost due to the insured's inability to work.  An individual policy covers only the wage earner and does not cover family members.  If another family member produces income, then that person must obtain his/her own Disability insurance.

Disability income insurance policies vary as to:
1. the definition of disability,
2. the amount of the payment,
3. the Elimination Period (time before benefits are payable),
4. the Maximum Benefit Period,
5. and the relationship to workers compensation benefits.

Disability Definitions

Total Disability

The definition of disability varies from policy to policy, but the traditional definition specifies that total disability is the "inability to work at any gainful occupation” (referred to as “Any Occ”).  Under this definition, if the insured can do any job - for even a portion of his former income - the insured is not considered totally disabled.  Some older policies require that the insured must also be confined to the house and under the treatment of a doctor.  This tightly constructed definition may not be allowed in several states.  A more liberal and current definition defines total disability is the "inability to perform the duties of any occupation for which he is reasonably suited by education, training, or experience.”  Another definition is "inability to perform all of the substantial and material duties of his regular occupation.”  (Referred to generally as “His Occ”)

A typical disability definition states that for a specified time after the beginning of the disability, the insured is totally disabled if he is completely unable to engage in his occupation (His Occ).  After the specific time period, commonly one, two or five years, the insured is considered totally disabled only if he is unable to perform the duties of any occupation for which he is reasonably suited by education, training or experience (“Any Occ”).



Partial Disability

Contracts may provide partial disability benefits, particularly in the case of disability caused by accident.  Partial disability is often defined as the "inability of the insured to perform one or more of the important duties of his occupation.”  Some policies provide that benefits are only payable for a partial disability immediately following a period of total disability for which benefits were payable.  The partial disability benefit usually pays a percentage (usually 50%) of the weekly or monthly indemnity payable for total disability for a limited period (usually three to six months).

Policies may provide benefits for residual disabilities.  A residual disability benefit provides benefits for loss of earnings after a return to work from total disability, if the insured cannot earn as much as he did prior to the disability.  The residual benefit is expressed as a percentage of the amount payable for total disability.

Amount of Benefits

The amount of the weekly or monthly payment applied for is usually based on the insured's earnings and is usually limited to a percentage of the insured's earned income.  The benefits may be capped (such as:  75% of stated annual income, with a maximum monthly benefit of $5,000).

Special care should always be taken in computing the benefit amount.  There can be wide variances in qualifications, and all sources of income must be stated.  It should be emphasized that overstating income so that the benefit maximum can be increased, can, at the very least, create an anti-selection element; and can even be grounds for denying benefits at time of disability.  Reporting of income vary by company and policy, and the reporting requirements must be stringently followed.

Probation Period

The probationary period provision applies to sickness and disabilities, and states that no benefits will be paid for sickness contracted during the first few days of the policy period.  In effect, it protects the company from an illness that existed before the policy inception date, and said illness was unknown.  This probationary period is commonly fifteen days.  The Probationary Period does not apply to disabilities caused by accident, as, obviously, accidents are not predictable.

Elimination Period

The Elimination Period is the period of time immediately after the onset of the disability measured in time (usually days) during which benefits are not payable.  The Elimination Period is similar to a deductible, however deductibles are usually expressed in dollar amounts.  The purpose is to eliminate small claims, as the insured is expected to be able to provide for short disability periods.  Many employers have a salary continuance plan, either formal or informal, before the Disability Insurance begins.

Elimination periods can range from three days to one year but usually are 7, 14, 30, 60, 90, and 180 days, (30 days being the most popular).  Usually, the accident coverage either has no Elimination Period or, infrequently, the Elimination Period is the same as for the sickness coverage.  Policies may provide that if the insured is disabled beyond the Elimination Period, benefits will be paid retroactively back to the first day of the disability.

Maximum Benefit Period

The Maximum Benefit Period is the length of time disability benefits will be paid under the contract and can range from six months to lifetime (if disability caused by accident).  The most common Maximum Benefit Periods are 1, 2, 3, 5, and 10 years, and to age 65.  Policies may provide for a lifetime sickness benefit period for any period of disability commencing before the insured reaches 50 and is usually available only with a lifetime accident maximum.  Disability income policies are classified as long or short term, based on the length of the sickness Maximum Benefit Period.

C.A.
Doctor Johnson, a Medical Doctor and a Surgeon, is leaving the staff of a hospital, and is starting his own practice.  One of his prime considerations is the loss of income should he become disabled since he no longer has a large hospital to rely upon for lost income.
Obviously, he must have Total Disability coverage since surgery will be a large part of his income; he will want to obtain a policy that defines disability as “inability to perform all of the substantial and material duties of his regular occupation (referred to as “his occ"). He should try to get a policy that allows his sufficient time to establish a practice should he be unable to operate before the plan changes to partial disability (any occ).
He should also investigate a residual disability provision,  as if he loses his ability to perform surgery, this would help him make up the difference in his income.
The amount of benefits available may be a problem here, as if he has no track record of being self employed, the company rules will in most cases, take a conservative approach.  He may be restricted to a lower percentage of his former income until such time that a pattern of earnings can be established.
The doctor will have to determine how long he can continue financially without income, and then determine the Elimination Period.  Depending upon his savings and any outside income (such as from investments), he would pick at least 30 days.
The Maximum Benefit Period will depend upon his age and the number of years before normal retirement.  Also, he must weigh the cost of the policy against the benefits desired, particularly in the benefit period.  If it is affordable, a period to age 65 would be attractive.  However, considering that if he became disabled and was unable to perform surgery, there is a good probability that he could still practice medicine in another field.

                                                                                                                (Continued)
      Later, if the doctor takes on a partner, and a buy-sell agreement is in effect, they should consider a policy covering the buy-sell agreement whereby if one partner become disabled, then funds will be available to buy out the partner.  These policies usually have a one-year Elimination Period with a monthly benefit of 1 to 2 years.


SPECIAL FORMS OF DISABILITY INCOME INSURANCE
Disability Income Insurance Under Life Policies

Disability income insurance may be offered as a rider to a life insurance policy that provides for a monthly indemnity in the event of total disability before a certain age (usually 55 or 60).  The amount of the monthly benefit is a function of the face amount of the life insurance and normally has a six month Elimination Period.  The Maximum Benefit Period is “to - age – 65”.  Frequently there is a provision that provides that if the insured is still, and continually, disabled at the end of the benefit period, then the life insurance benefits will be paid as an endowment and the policy premium will be waived.  Optional benefits, such as for partial disability, are usually not available.

Waiver of Premium in cases of disability is traditionally available on most life insurance policies (but does not pay monthly indemnity payments).

BUSINESS OVERHEAD EXPENSE BENEFITS

Business Overhead Expense insurance provides funds to pay certain expenses required for the operation of a business or professional office for a specified time period when the insured owner is totally disabled.  This is an area that is very important to self-employed professionals and business owners.  This is a highly specialized field of health insurance, and additional concentrated training is necessary to properly represent this product, which is beyond the scope of this text.  It is closely related to Key Employee Insurance, and Buy & Sell Agreements, described below.

KEY EMPLOYEE DISABILITY INSURANCE

Key Employee coverage pays a monthly benefit to a business for the purpose of hiring and training additional help or services, when a Key Employee is disabled.  Practically, it has a two-pronged effect: it covers the disabled person’s salary, and pays for a temporary replacement during the period of disability.


BUY AND SELL AGREEMENTS

Closely linked to the business uses of Disability insurance as outlined above, Buy and Sell Agreements specify the terms partner(s) or stockholder(s) by which a disabled partner’s, or stockholder’s, interest can be purchased by the other partner(s) or stockholder(s), with the insurance policy providing the necessary funds for the buy-out.  Policy terms must mirror the Buy & Sell Agreement as to the Elimination Period, amount of benefit, and benefit period.  These policies usually have a one-year Elimination Period with a monthly benefit period of 1 – 2 years.

ACCIDENTAL DEATH AND DISMEMBERMENT

Accidental Death policies provide a death benefit which is payable in the event of death resulting from accidental bodily injury.  An Accidental Death and Dismemberment policy also provides benefits for loss of limbs or sight (dismemberment coverage).

Accidental Death and Dismemberment (AD&D) is usually presented as a schedule listing various dismemberment’s and losses of sight covered by the policy, and for which a specified sum will be paid to the insured.  The amounts may be expressed as a multiple of the weekly indemnity amount, or if the policy does not have weekly disability income benefits, it is expressed as a percentage of the death benefit limit, or as a percentage of the Capital Sum (policy limit).


SAMPLE SCHEDULE
Loss of: Sum equal to
Weekly indemnity for:
Both hands, or feet, or sight of both eyes 200 weeks
One hand and one foot 200 weeks
Either hand or foot and sight of one eye 200 weeks
Either hand or foot 100 weeks
Sight of one eye  65 weeks
Thumb and index finger of either hand  50 weeks

The dismemberment feature provides a lump sum payment that can be used during the rehabilitation period and job training.  If the policy also provides disability income, in most situations when the dismemberment amount has been paid, the disability income payments also stop.  If during a disability period, a dismemberment loss is suffered, the insured will be paid disability income up to the maximum dismemberment period.

Most AD&D policies provide that if a loss of limb or sight occurs within 90 days of an accident, the sums in the schedule will be paid.

CA
Jim Brown works in warehouse and travels 15 miles each way to work, in very heavy traffic.  His employer furnishes health insurance in case of sickness, but Brown is concerned about being injured in an accident.
The employer recently provided an Accidental Death and Dismemberment policy that pays for 90 days of weekly indemnity for disability and a schedule for dismemberment.  His death benefit is $20,000 and weekly indemnity is $200.
Brown loses an arm at work when a crate in the warehouse is dislodged and falls on him.  His medical costs are covered by the group health plan and by Workers Compensation.  Workers Compensation provides a small income after Brown is released from medical care.  However, his dismemberment proceeds of  $20,000 can be used for job training and rehabilitation not otherwise covered.

NOTE:  Many policies offer a set amount of Accidental Death benefits, and Dismemberment is a factor of the death amount.  In that case, with a death benefit of $20,000, the policy would usually offer 50% of the death amount, or $10.000 in this case.



MEDICAL EXPENSE INSURANCE

Medical expense insurance provides benefit payments for medical care.  The providing of benefits may be by:
1. reimbursement to the policyholders for medical expenses incurred,
2. paying those who provide the services directly,
3. paying a set amount regardless of the amount charged for medical expenses.  (This is referred to as an “Indemnity policy”).
A policy may cover an individual, his or her spouse and children.

The categories generally accepted, for Medical Expense Insurance, are
1. basic medical expense insurance,
2. major medical insurance,
3. comprehensive medical insurance and
4. special policies.




BASIC MEDICAL EXPENSE POLICIES

Basic coverages provided by an individual medical expense policy include basic hospital expense, basic surgical expense, and basic medical expense.  (The term basic medical expense is used in a more narrow sense to mean the non-surgical services of a physician).  These three basic coverages may be sold together, or each coverage can be offered on a stand-alone basis.

Basic hospital expense coverage provides benefits for daily hospital room and board and miscellaneous hospital expenses while the insured person is confined to the hospital.  The policy may provide for a certain dollar amount for the daily hospital room and board benefit, (such as $100 a day units, with a maximum of a multiple, i.e. $500 maximum) although paying the semi-private room rate (as a maximum) is gaining in popularity.

Policies usually provide for additional benefits while the insured is in an intensive care unit, either as an included benefit, or as an additional (“add-on”) benefit.  The amount paid for Intensive Care is frequently a multiple of the daily benefit amount.

A time limit for coverage is also specified, with usual dates of 30 or 60 days.

Miscellaneous hospital expenses include such items as dressings, drugs, charges for operating rooms, anesthetics, services of anesthetists, lab work, and x-ray treatments.  Usually coverage is limited to a certain dollar amount, such as $2,000, but may also be limited as a multiple of the daily hospital benefit charge.  (For example, up to 15 times the daily hospital benefit maximum.)

Basic surgical expense coverage provides benefits for the surgical services of a physician performed in or out of the hospital.  Surgical expense benefits are usually limited to a dollar amount, although they may be expressed as multiples of the hospital benefit maximum.  Usually a schedule of operations is attached to the policy and the maximum amount payable for each operation is listed.  A surgical expense policy may be sold as part of a hospital and medical expense policy, or on a stand-alone basis.

Higher benefits are paid for the more serious and complicated surgeries.  While the surgical schedule cannot refer to all surgeries, for those that are not listed in the schedule are covered on the same basis as comparable operations that are listed.  Surgical schedules may also assign a relative value (unit) to each procedure, and the amount to be paid by the insurer is derived by formula using the relative value unit.

Historically, basic medical expense policies covered the insured only while confined to a hospital and limited to a dollar amount per day, for a specific number of days.  Many policies now include diagnostic x-ray and laboratory expenses on an outpatient basis, with a dollar limit.  Radiotherapy on an outpatient may be available, with a maximum limit.


Emergency hospital treatment with a per-visit limitation may be included with a limit per trip.
Basic medical expense policies may also include nursing care coverage, which provides payment for private duty nursing care by order of a doctor while the insured is in the hospital.  The benefit is usually limited to a maximum amount per day for a maximum number of days.

In addition, maternity expenses and or indemnity payment may be offered with some plans.  Maternity expense benefits usually provide limited coverage for medical expenses due to pregnancy and are based on a multiple of the daily hospital room benefit.  In some plans, a flat amount is paid and has no relation to the actual expenses incurred (indemnity coverage).  In some cases, the surgical schedule may provide a specified physician's fee for delivery.

Except for the Maternity Expense benefit, other policy benefits do not cover normal childbirth.  However, complications of pregnancy specifically described may be covered.

Extended care benefits may also be provided by the payment of a maximum daily benefit for confinement in a skilled nursing facility.  There is usually a waiting period after hospital discharge (14 days is usual).  The benefit amount payable is usually one half of what the policy would pay for hospital confinement.  The benefit period varies from one month to one year.

Some basic medical expense policies have deductibles for each hospital confinement.

C.A.
John purchases a Basic Medical Policy that pays for hospital expenses and sold in $100 units.  John elects a 5-unit plan, which would pay $500 per day for hospital room and board.
Intensive Care Benefit provides for 3 times the daily benefit, or $1500 while in Intensive Care.
This plan pays up to 5 times the daily benefit, for miscellaneous hospital expenses, or $2500.
This plan also offers Surgical benefits of 5 times the daily benefit for one surgeon, and 50% of that amount for a second surgeon when necessary.  It would pay $2500 for a surgeon and $1250 for a second surgeon.
John may purchase an outpatient rider, which pays a maximum of 50% of the daily benefit for emergency room and other outpatient surgeries.  It also provides diagnostic x-ray and laboratory expenses on an outpatient basis, with a maximum of $2,000.
There is no deductible under this plan. If John should later elect to superimpose a Major Medical plan on top of this Basic policy, then the Major Medical deductibles will not kick in until the Basic plan has paid the maximum benefits.







MAJOR MEDICAL INSURANCE

Major medical insurance provides benefits for serious or prolonged injury or illness.  These policies may be written to complement basic medical expense policies, however this is becoming less attractive as a choice.  Major Medical Insurance is the most popular medical insurance plan, by far, on an individual and group basis.  Most employees have been covered by a Major Medical Plan, and when it become necessary to purchase their own coverage (without employer participation) they understandably want the same type of comprehensive coverage.

Deductibles are a necessary function of the Major Medical policy, which keeps the cost of insurance down because of the elimination of small claims whose expenses to administer frequently exceed the claims payment.  In addition, participation in costs by the insured presupposes a high interest of the insured in the control of benefits.  Deductibles are usually defined as a specific dollar amount paid for covered medical expenses.  If a Major Medical Policy is superimposed on a Basic Medical plan, then the Deductible may not be incurred until the Basic plan has paid the maximum benefits under its coverage.

The deductible may apply to each accident or illness, or to each calendar year, and to each covered person.  Most policies provide that if a family is insured, a maximum of three deductibles apply per family per year: that is, if three family members have “met their deductible” during the specified deductible period (usually a calendar year), then any medical costs experienced by a fourth family member would not be subject to a deductible.

There is usually a common accident provision, which states that if members of a family are injured in a common accident, only one deductible applies.  Many companies also include a carry-over provision which states, for example, that expenses incurred during the last three months of a calendar year may be used toward the deductible in the following year, provided the deductible for the prior year has not been met.

Most policies have a coinsurance provision.  A coinsurance provision provides for the sharing of medical costs after the deductible has been met (satisfied), generally up to a maximum, at which point the insurer pays 100% of medical costs.  Typically, coinsurance is 90/10 (the insured pays 10% of the medical costs after satisfying the deductible, the insurer paying 90%); 80/20; 75/25, or 50/50.  The more that the insured has to pay, the lower the premium.  As an example, a 90/10 plan would be noticeably more expensive than a 75/25 plan.

The maximum benefit payable under a Major Medical policy applies to each person, so each member of an insured family is insured for the maximum benefit.  The benefit also is expressed as a “lifetime” benefit.  If an insured had medical expenses after deductible and coinsurance of the policy maximum, the insurer would not pay any further claims.  If the insured’s spouse had medical claims, they would be separate and distinctive from the insured’s claims when calculating the maximum benefit.  Many major medical policies have a restoration of benefits provision which allow a percentage or (usually) a dollar amount that can be restored each year the policy is in force.  The Restoration of Benefits provision may, or may not, be affected by claims paid.

The coverage provisions of major medical expense policies are very broad.  The term covered expenses is usually defined to include doctors fees, nurses fees, hospital charges for room and board, miscellaneous hospital charges, charges in connection with pregnancies, cosmetic surgery, nervous or mental disorders, and alcoholism or drug addiction.

Coverage is usually provided on a blanket basis, without specifying individual dollar limitations on the coverage of various medical expenses.  But there may be “inside” limits, which apply to specific expenses (such as hospital room and board and surgery) and may be expressed as a maximum dollar amount.  If there are inside limits, they are considerably higher than the amounts allowed under basic medical policies.

C.A.
Margaret has an individual Major Medical policy with a deductible of $1,000  (3-deductibles per family maximum), 80/20 coinsurance, $1500 out-of pocket, lifetime benefits of $1,000,00, $10,000 maximum for mental and nervous disorders, 3-month deductible carryover, 2-year pre-existing condition, and a waiver of deductible for injuries as the result of an accident.
Margaret has no idea as to what she has!
At the very least, the agent should explain to her the following:
Before benefits are paid by the insurer, every calendar year she must pay the first $1,000 of every medical expense including hospital, doctors offices, surgeons, medication, etc.
After she has paid the first $1,000, the insurer will pay 80% of all medical bills, until such time that she has paid an additional $1,500 out of her pocket, for a total of $2,500 that she has to pay.  After $50,000, the insurer will pay 100% of all approved medical expenses.  (She has no family, but if she did, after 3 members of the family have met their deductible in any calendar year, deductibles of other family members would be waived.)
If she is injured in an accident, she does not have to pay a deductible, and the insurer will start paying 80% of the medical bill automatically.
Any medical costs that were incurred the last 3 months of the year and which have not been used to meet the deductible for that year, can be carried forward to the following year.
In case she needs medical attention for mental or nervous disorders, the plan will pay a maximum of $10,000 for any hospitalization or treatment.                        
     Any medical condition that exists for a period not exceeding two years, will not be covered
until the policy has been in force for two years.  (Note:  If Margaret had been covered under a
group plan, and her COBRA benefits have expired and her previous company cannot offer her additional coverage, she may be eligible for a plan wherein the pre-existing conditions will be waived under provisions of the HIPAA of 1996 – discussed in detail later in the text).







COMPREHENSIVE MEDICAL INSURANCE

The popularity of Comprehensive Medical insurance has been replaced by Major Medical plans, as Major Medical insurance has become “comprehensive” and so competitive in price, that the original Comprehensive medical insurance concept is not often used.  Comprehensive Medical Insurance in this context, is a combination of basic medical expense coverage and major medical coverage.  The first dollars of expense are covered under the basic medical policy, usually with a low ($50 or $ 100) deductible.  The major medical portion of the policy begins to pay when the benefits of the underlying basic medical expense policy are exhausted.  In effect the basic medical expense portion of the policy provides a deductible before the major medical coverage applies.

A corridor deductible is frequently found in a comprehensive policy, which is a fixed amount the insured pays after the basic coverage is exhausted - but before the major medical coverage benefits are payable.  To illustrate, the basic medical coverage pays until its limits are exhausted.  At that point a deductible must be satisfied.  When medical expenses exceed “A” (the amount of the basic plan) plus “B” (the deductible), the major medical coverage goes into effect.  With these arrangements, the major medical benefits is equal to a percentage of the total medical expense (see coinsurance description above).  An individual comprehensive medical insurance policy would have to meet the minimum standards requirements for basic hospital expense policies, basic medical-surgical expense policies and major medical expense policies.



SPECIAL MEDICAL EXPENSE INSURANCE POLICIES

There are a variety of special health insurance policies providing limited coverage, such as:
Specified Disease or Dread Disease insurance which provides a variety of benefits for only certain (specified) diseases, usually cancer or heart disease.  Benefits are usually on a scheduled basis, paying an indemnity amount depending upon the procedure or type of disease.  Recently, plans that pay a specified amount – usually in $10,000 increments – upon diagnosis of a particular disease (usually cancer) have become quite popular.  These plans are designed to pay in addition to any medical expense insurance (coordination of benefits provisions on other health insurance policies do not apply) and are used for paying added expenses that accrue when a person contracts the particular disease or condition.

Hospital Indemnity insurance pays a specified sum on a daily, weekly or monthly basis while the insured is confined to a hospital.  The amount of the benefit is not related to expenses incurred or to wages lost while the insured is hospitalized.  These plans are marketed as individual or franchise-group plans.  They are attractive to the industry as claims payment are simple (must be in the hospital) and amounts are modest.  Usually these products are Guaranteed Issue.

Accident - only insurance provides coverage for injury from accident and excludes sickness.  Benefits may be paid for all or any of the following: death, disability, dismemberment, or hospital and medical expenses.  Accident - only coverage is a very inexpensive type of coverage and frequently is added to other plans.


C.A.
Felix considers purchasing a “Cancer Plan” that pays benefits to an insured when he is diagnosed as having cancer.  The amount of the benefit depends upon the type and severity of the cancer.  If Felix had ever been diagnosed with cancer, he could not have qualified for the policy.
Felix is approached by an agent who represents a company that offers a plans that pays a pre-determined flat amount as soon as cancer is diagnosed, and is sold in units of $10,000.  Felix likes this plan because it pays the full amount regardless of the type or severity of the cancer.  He purchases 5 units ($50,000).
Either plan pays in addition to his health insurance plan.  Felix is later diagnosed with lung cancer, which involved removing the cancer.  His insurance covered the medical costs, however he went to Sloan-Kettering which specializes in cancer research.  Since this clinic was not an approved clinic under his PPO health plan, he had to pay some costs out of his own pocket, plus he had to pay for travel expenses for he and his wife, and pay lodgings and meals for his wife while he was in the hospital.  The $50,000 covered most of the additional cost.

Annual Release of Australian Offshore Petroleum Exploration Acreage



2011 Offshore Petroleum Exploration Acreage Release
The Australian Government encourages investment in petroleum exploration through the annual release of offshore petroleum exploration acreage.  The Acreage Release is underpinned by Australia's stable economic environment and well-established regulatory framework for offshore petroleum actives.
Follow these  to the:
  • Offshore Petroleum Exploration Acreage Release

WELCOME TO THE 2010 OFFSHORE PETROLEUM EXPLORATION ACREAGE RELEASE

The Australian Government encourages investment in petroleum exploration through the annual release of offshore petroleum exploration acreage.  The Acreage Release is underpinned by Australia's stable economic environment and well-established regulatory framework for offshore petroleum actives. 
The 2010 Offshore Petroleum Exploration Acreage Release comprises 31 areas, located across five basins in Commonwealth waters in the offshore areas of Western Australia (26 areas), the Northern Territory (1 area), the Territory of Ashmore and Cartier Islands (2 areas) and South Australia (2 areas).
Release areas have been carefully selected to offer the global petroleum exploration industry a variety of investment opportunities. Areas vary in size, level of existing geological knowledge and are located in a range of water depths. All selected areas are supported by pre-competitive geological and geophysical data and analysis undertaken by Geoscience Australia.
The 2010 Acreage Release package contains the following information:

2010 RELEASE AREAS AND GEOLOGYThis section contains detail on the petroleum prospectivity and geological settings of the five basins containing the Release areas, to assist explorers in their evaluations prior to bidding.
EXPLORING AND INVESTING IN AUSTRALIA (OVERVIEW FOR APPLICANTS) This section provides an introduction to the legislative framework and investment environment for companies interested in becoming involved in the Australian offshore petroleum exploration industry. It also provides an overview of relevant Commonwealth legislation, along with details of key initiatives and programs that may be of interest to potential investors.
BIDDING AND ASSESSTMENT (GUIDANCE NOTES FOR APPLICANTS)This section sets out information for companies interested in bidding on areas released in the 2010 Offshore Petroleum Exploration Acreage Release.
It contains ‘quicklook maps' of the release areas; special notices outlining the rights and interests of third parties; the requirements for developing and submitting a competitive work program bid; the selection criteria used by the Joint Authority in assessing bids; and the permit conditions and administration requirements that would apply to exploration permits granted as a result of this process.
FACT SHEETSThis section contains fact sheets for applicants, title holders and interested parties and covers a wide range of topics related to offshore petroleum exploration and regulation in Australia.
DATA This section contains a summary of available seismic, well and sample data to assist explorers in evaluating Release areas.
PRODUCTS AND SERVICES
The section contains details of Commercial Services available to assist explorers in evaluating Release areas, along with links to petroleum related services provided by the Department of Resources, Energy and Tourism, Geoscience Australia, and Industry Associations. 
Areas that do not attract bids during the initial release may be re-released for further bidding.  The re-release of an area is at the discretion of the Joint Authority.  Areas that are currently open for bidding can be found on the Areas Currently Open for Bidding page.
Please note: the Acreage Release websites contain links to external organisations and businesses outside of the Department's domain. Linking to external websites does not imply endorsement of the products, services and opinion offered by those sites.

Offshore Petroleum Exploration in Australia



The Australian Government administers policy which encourages petroleum exploration in Australia's offshore areas. The Department of Resources, Energy and Tourism strives to provide a stable, transparent and internationally competitive offshore exploration investment regime. Each year, following consultation with stakeholders, the Department releases offshore petroleum exploration acreage for competitive bidding by prospective explorers.
The annual Offshore Petroleum Exploration Acreage Release is a key part of the Australian Government’s strategy to encourage further petroleum exploration in Australia’s offshore waters. The regular release of acreage enables industry to undertake longer term planning and provides certainty in the release process. The release is supported by a comprehensive information package that ensures access to pre-competitive geological and geophysical data and analysis, along with the provision of quality information about issues that may impact on successful applicants.
The Department also manages, in partnership with the states and the Northern Territory, the assessment of applications and the award of exploration permits. The primary objective in awarding an exploration permit is to select the bid most likely to achieve the fullest assessment of the petroleum potential within the permit area in the minimum guaranteed period of the permit. Following discovery of a petroleum resource, the successful explorer will have the right to produce the resource and to construct pipelines and other infrastructure, subject to development approvals to ensure appropriate regard to safety, the environment and good oil field practice.
Follow these links to:

  • the Offshore Petroleum Exploration Acreage Release
  • offshore petroleum exploration areas open for bidding
  • offshore petroleum regulations and legislation
  • Australian Petroleum News - free occasional industry newsletter
  • Government contacts list

periods of petroleum exploration in Morocco


The first time I visited Morocco, I saw postcards that featured goats perched in Argan trees. Sure, I thought, this is a gag. Surely they must have either tied stuffed goats to branches or retouched photos. So the first time I visited Argan Country, near Essaouira and Agadir, boy, was I surprised. There were real goats in the trees! Munching away! I soon found out that was going on. The goats were exclusively found in argan trees.Argan is a relative of the olive, and the goats were eating the argan fruit. Argan is grown exclusively in the southwest region of Morocco. It is difficult to cultivate and as a result, wild trees are treasured. Argan oil is prized in Morocco and recently has been discovered by the West. It has been used for centuries for cooking and cosmetics. The oil is extracted from the kernel of the pits.

There are many women’s cooperatives in the region that help poor women with employment and educate their children as well. It is fascinating to see how experienced “crackers” take the small pit (imagine an olive pit), set it against a large stone and with another small stone, cracks the pit open in one try. I’ve tried it and got a bloody thumb as my reward! Then the kernels are ground into a past with the oil running out. You can see this is a very tedious and time-consuming procedure that accounts for the high price of argan products.
The First Period between 1900 and 1928, was largely undertaken by the Compagnie Francaise des Petroles (CFP) and focused around in the Rharb Basin around oil seeps and geomorphological features. The fields were put onstream in the 1930′s and production averaged around 100 bo/d, peaking around 2400 bo/d in 1954. CFP discovered the Ain Hamra oil pool in 1923, which has a Late Miocene and Pliocene clastic reservoir in a sequences of thrusted sand lenses and produced a total of 90,000 barrels of oil.

The creation of the BRPM (Bureau de Recherchés et d‘Exploitations Minière) in 1928, signified the start of the Second Period of Petroleum Exploration from 1928 to 1958. The BRPM was tasked with developing the mining industry, which included the exploration of hydrocarbons, through Elf Erap and Compagnie Française des Pétroles (which later became Total CFP). In 1929, BRPM created Société Cherifienne des Petroles (SCP), which was specifically tasked to explore for oil and gas. The earliest seismic reflection techniques were used in the Rharb and Prerif basins in 1935. Although there was no significant exploration during WWII ,between 1939 and 1945, the “Société des Schistes Bitumineux de Tanger” developed and operated a 80 tons per day oil shale pilot plant in the Upper Cretaceous Tangier oil shales, in Northern Morocco.

The first seismic surveys in the Essaouira, Souss and Guercif basins were shot in 1955. Oil and Gas discoveries were made in the Prerif Ridges and in the Sidi Fili trend and around production rose from around 100 bo/d in 1939 to 2,400 bo/d by 1954. The first natural gas was discovered in the Essaouira Basin at Kechoula and Djebel Jeer in 1957 and 1958 respectively.

The 1958 Hydrocarbon Law enable foreign company participation on 50:50 profit share basis with the BRPM. The new terms successfully attracted foreign investors and by 1968 Agip, Apex, Elf-Erap, Exxon and Preussag were exploring for oil in most of the basins. In the 1970s over forty companies had held exploration licences in Morocco and more than 176 wells were drilled in most basins, through the period. Fifteen commercial oil and gas accumulations fields were discovered, including Morocco’s largest discovery at Sidi Rhalem (1961) in the Essaouira Basin and Exxon discovered Morocco’s only offshore field, Ras Juby (1969). By the end of 1981, cumulative production was 9 million barrels of oil and 35 BCF of gas and most of the new entrants had withdrawn from the country due to a lack of exploration success.

The Office National de Recherches et d’Exploitations Pétrolières (ONAREP) was created by the Moroccan government in 1981, with a mandate to explore for hydrocarbons in Morocco both by itself and jointly with foreign petroleum companies. Between 1981 and 1990, ONAREP drilled 85 wells with50 drilled jointly with international companies. This activity led to the discovery of the country’s largest gas field at Meskala in the Essaouira Basin in 1981 as well as several biogenic gas accumulations in the Rharb Basin. Fourteen companies were awarded 23 exploration licences during this period, but by 1993 they had relinquished all the licences.

In 1992, the government promulgated a new hydrocarbon law and in 1994, ONAREP promoted three exploration areas: the Inter Atlas region in the northeast, the Doukkala Basin along the Atlantic coast south of Casablanca and the offshore Tarfaya-Infi Basin. Between 1997 and 1999, foreign companies signed 16 exploration licences and four (Conoco Enterprise, Lasmo and Shell) signed offshore reconnaissance licences. Sixteen exploration and appraisal wells were drilled in Morocco between 1990 and 2000, fifteen were drilled onshore, which led to the discovery of three gas fields: Lalla Yto (1991), Ouled Brih (1992) and Zhana (1998). One well was drilled offshore (Tarfaya 1. 1990), was offshore plugged and abandoned dry.

The Hydrocarbon Law was amended in 2000 providing Oil and Gas investors with more attractive fiscal terms. In 2003, ONHYM was created as a merger of ONAREP and BRPM, beginning a new era with a dynamic strategy and improved synergy to adequately assess both the Hydrocarbon and Mining Potential of Morocco. The countery is still perceived as being underexplored in terms of petroleum exploration, with a comparatively low number of exploration wells in each basin. The number of exploration concepts tested has been very limited and many of the wells that were drilled did not reach their objectives because they were ei

Petroleum exploration in the Arctic as Morocco


Oil drilling in the Arctic. Facing a freeze. Governments are reviewing plans to open Arctic waters to oilmen.While the exploration of oil typically occurs during the winter months when caribou and birds are absent from the 1002 Area, there are several arctic-adapted
The exploration of the Arctic for petroleum is more technically and physically challenging than for any other environment. However, with increases in technology and continuing high oil prices the region is now receiving the interest of the petroleum industry.

There are 19 geological basins making up the Arctic region. Some of these basins have experienced oil and gas exploration, most notably the Alaska North Slope where oil was first produced in 1968 from Prudhoe Bay. However, only half the basins - such as the Beaufort Sea and the West Barents Sea - have been explored.
Location of Arctic Basins assessed by the USGS

A 2008 United States Geological Survey estimates that areas north of the Arctic Circle have 90 billion barrels of undiscovered, technically recoverable oil (and 44 billion barrels of natural gas liquids ) in 25 geologically defined areas thought to have potential for petroleum. This represents 13% of the undiscovered oil in the world. Of the estimated totals, more than half of the undiscovered oil resources are estimated to occur in just three geologic provinces - Arctic Alaska, the Amerasia Basin, and the East Greenland Rift Basins. More than 70% of the mean undiscovered oil resources is estimated to occur in five provinces: Arctic Alaska, Amerasia Basin, East Greenland Rift Basins, East Barents Basins, and West Greenland–East Canada. It is further estimated that approximately 84% of the undiscovered oil and gas occurs offshore. The USGS did not consider economic factors such as the effects of permanent sea ice or oceanic water depth in its assessment of undiscovered oil and gas resources. This assessment is lower than a 2000 survey, which had included lands south of the arctic circle.[1][2][3]

A recent study carried out by Wood Mackenzie on the Arctic potential comments that the likely remaining reserves will be 75% natural gas and 25% oil. It highlights four basins that are likely to be the focus of the petroleum industry in the upcoming years: the Kronprins Christian Basin, which is likely to have large reserves, the southwest Greenland basin, due to its proximity to markets, and the more oil-prone basins of Laptev and Baffin Bay.

Extensive drilling was done in the Canadian Arctic during the 1970s and 1980s by such companies as Panarctic Oils Ltd., Petro Canada and Dome Petroleum. After 176 wells were drilled at billions of dollars of cost, approximately 1.9 billion barrels (300×106 m3) of oil and 19.8 trillion cubic feet (560×109 m3) of natural gas were found. These discoveries were insufficient to justify development, and all the wells which were drilled were plugged and abandoned.

Drilling in the Canadian Arctic turned out to be expensive and dangerous. The geology of the Canadian Arctic turned out to be far more complex than oil-producing regions like the Gulf of Mexico. It was discovered to be gas prone rather than oil prone (i.e. most of the oil had been transformed into natural gas by geological processes), and most of the reservoirs had been fractured by tectonic activity, allowing most of the petroleum which might at one time have been present to leak out.

In June 2007, a group of Russian geologists returned from a six-week voyage on a nuclear icebreaker 50 Let Pobedy, the expedition called Arktika 2007. They had travelled to the Lomonosov ridge, an underwater shelf in Russia's remote and inhospitable eastern Arctic Ocean.

According to Russia's media, the geologists returned with the "sensational news" that the Lomonosov ridge was linked to Russian Federation territory, boosting Russia's claim over the oil-and-gas rich triangle. The territory contained 10bn tonnes of gas and oil deposits, the scientists said.
In the early 2012 Russia plans to start the first commercial offshore oil drilling in the Arctic, on Prirazlomnaya platform in the Pechora Sea.[6] The platform will be the first Arctic-class ice-resistant oil rig in the world.

Greenland is believed by some geologists to have some of the world’s largest remaining oil resources.Prospecting is taking place under the auspices of NUNAOIL, a partnership between the Greenland Home Rule Government and the Danish state. U.S. Geological Survey found in 2001 that the waters off north-eastern Greenland (north and south of the arctic circle) could contain up to 110 billion barrels (17×109 m3) of oil.[8]

Greenland has offered 8 license blocks for tender along its west coast by Baffin Bay. Currently 7 of those blocks have been bid for by a combination of multinational oil companies and the National Oil Company NUNAOIL. Companies that have participated successfully in the previous license rounds and have formed a partnership for the licenses with NUNAOIL are, DONG Energy, Chevron, ExxonMobil, Husky Energy, Cairn Energy. The area available known as the West Disko licensing round is of an interest due to its relative accessibility compared to other Arctic basins as the area remains largely free of ice. As well as a number of promising geological leads and prospects from the Paleocene era.

Jaouhar Ben Mbarek receives death threats

le matian by opening his bookstore as Hazgui Ezzeddine, father of Ben Mbarek Jaouhar, leader of the "Doustourna" found on his doorstep, a message of death threat against Jaouhar Ben Mbarek.

Contacted by Business News, Jaouhar Ben Mbarek confirmed the information but said that there were two different newspapers coupons, one of which announced the death of a militant movement occurred, a few weeks ago in which was glued to the photo of Ben Mbarek. He said "It was a clear message, I was threatened with death! ".

Responding to the question of possible suspicions, Ben Mbarek said the message was not signed and did not have a clue as to the identity of the sender. However, he filed a complaint and a police investigation is already underway, he added.
youssef has
Uncle | 17-01-2012 7:37 p.m.
Here is a forum. if you want to know who I am and not being pretentious as your teacher. I myself am a teacher in college, but not in Tunisia. the United States.
Here if it comforts you. but my message is not directed at your teacher, it is for us all. have mercy on our country and try to work together, let our quarrels. Now we are in a democratic process, build, and do not block the country. hello to the wise.
Deniers are.
And thus incites violence by their denial.
In total incapacity of any self-criticism.
They are detrimental to the fringe of the Democratic Ennahdha, I hope that existing and influential.
Know that we resist your threats.

Ben Ali: I saved the skin of Rached Ghannouchi!

"The only crime is to have Ben Ali was the President of the Republic of Tunisia for 23 years. He accepted the political process but not the humiliation and accusations disgusting and invented. "In questions of our colleagues to Attounissia, which were transmitted by his lawyer Akram Azouri Lebanon, the former president boot button.This testimony was needed to complete the contradictory versions of the main actors of the events that will place a January 14, 2011. But in the end nothing exciting in these statements. Ben Ali refuses to be the fall guy in history and experience concocted by the new conquerors. Back on the main passages ...
"Do you not think you need to apologize to the Tunisian people? "..." No answer "... The former president stubbornly defends his record, leading even some sarcastic pikes against his critics today. With a pity worthy of a former head of state, he understands that former civil servants and ministers, aged bedridden, were able to discard on him to preserve their freedom. He can not help, for against, defend Abdallah Kallel. His interior minister could not accuse him of instigating the torture of soldiers arrested in the case of Barraket Essahel. Except under duress ...
He is accused of overseeing the secret services directly parallel dodge and riposte. How could he give the order to bomb the city of Kasserine he who, throughout his reign, has never signed the decree for the execution of a death sentence. Even better, during the presidency of Bourguiba, he even managed to save from the gallows Rached Ghannouchi and several other leaders of Ennahdha. It took 24 years to discover that the sinister Ben Ali is not devoid of humor and mischief.
What the accused does one? Having gradually clocked politics and strengthen the party system, governed by the cult of personality? False and archi-false, he replies, in September, three radical parties were allowed and no decision without consulting the government or the committee concerned. To prove his good faith, Ben Ali does not rule out the possibility to return and appear before the Tunisian courts. But only if justice were to meet the requirements of a fair trial. And for now, we see rather a vendetta and a settling of accounts with the old political regime, says he injured. To illustrate his point, the sequestration of the hostages from the airport Tunis-Carthage 14 January, without a rogatory commission, has been signed.
What can we still blame him? The seizure of his beautiful family on whole sections of the national economy? Except he could not be aware of everything that is happening in the country. Maybe some of his close associates he hid some overruns, overruns if there was! But he never, ever has been reached on behalf of anyone to grant him privileges.
And the fabulous sums of money, plus the two kilos of cannabis and weapons found in his palace of Carthage and Sidi Dhrif, why does a tone found only two months after his departure as his personal residence has undergone several break-ins ? Extensive fraud and Ben Ali will not bother to reply. It's just like the tall tale of Leila Ben Ali accused of kohlrabi tons of gold, a charge immediately denied by the Central Bank. And toc!
To believe his answers, Ben Ali has done nothing wrong. He has made Tunisia a modern country as evidenced by many friendly countries although additional work was still lacking to advance freedom. In nobleman, Ben Ali is not vindictive and wants Tunisia to escape anarchy and darkness and it continues its path towards modernity. The "shameful and rigged justice of the victors, unable to succeed and fulfill their responsibilities" does not affect it. All he hopes is that his people do it justice ...
Political messages in all. Ben Ali is not as might have been shot thinking. The war against the new masters of the country is run. And he did not fail to denigrate their predictable victory in the elections of the Constituent Assembly after the activities of RCD have been frozen illegally. Three million members RCD prevented from enjoying their constitutional rights despite the International Treaty on Civil and Political Rights of 1996 ratified by Tunisia ...
Many of my face in the attacks of Ben Ali, but interspersed with a few charges, if proven true, would be a bombshell in the new political landscape. Politicians, some leaders of opposition parties have called on the 13 and January 14 to congratulate him after the famous speech of 13. None of them suspected, at that time, the plot hatched to overthrow long. For the former president confirmed and signed. There have been a plot to turn up the heat against him and push him to leave. And he never ordered the defense minister to break down the anti-terrorist officers.
Phone calls between Ben Ali, his ministers of Interior and Defense, and General Ali and Rachid Ammar Seriate are all recorded. The former president will not assume its political responsibility and historical, merely passing the buck to his opponents. But we must admit that this latest offensive can hurt. These famous recordings will they one day announced to justice and historians? Nothing is certain ...

Exploration articles,Petroleum geology


Petroleum geology refers to the specific set of geological disciplines that are applied to the search for hydrocarbons (oil exploration). .... Furthermore reservoir properties, connectivity, hydrocarbon type and gas-oil and oil-water contacts are ...Aller à Elements of a petroleum prospect‎: Five geological factors have to be present for a prospect to work and if any of them fail neither oil nor gas will .The practice of locating natural gas and petroleum deposits has been ... looking for seepages of oil or gas emitted from underground before they had any clue that ...Exploration for natural gas typically begins with geologists examining the .... not the formations have the potential for containing hydrocarbons like natural gas.
The practice of locating natural gas and petroleum deposits has been transformed dramatically in the last 20 years with the advent of extremely advanced, ingenious technology. In the early days of the industry, the only way of locating underground petroleum and natural gas deposits was to search for surface evidence of these underground formations. Those searching for natural gas deposits were forced to scour the earth, looking for seepages of oil or gas emitted from underground before they had any clue that there were deposits underneath. However, because such a low proportion of petroleum and natural gas deposits actually seep to the surface, this made for a very inefficient and difficult exploration process. As the demand for fossil fuel energy has increased dramatically over the past years, so has the necessity for more accurate methods of locating these deposits.

Technology has allowed for a remarkable increase in the success rate of locating natural gas reservoirs. In this section, it will be outlined how geologists and geophysicists use technology and knowledge of the properties of underground natural gas deposits to gather data that can later be interpreted and used to make educated guesses as to where natural gas deposits exist. However, it must be remembered that the process of exploring for natural gas and petroleum deposits is characteristically an uncertain one, due to the complexity of searching for something that is often thousands of feet below ground.


Exploration for natural gas typically begins with geologists examining the surface structure of the earth, and determining areas where it is geologically likely that petroleum or gas deposits might exist. It was discovered in the mid 1800s that ‘anticlinal slopes’ had a particularly increased chance of containing petroleum or gas deposits. These anticlinal slopes are areas where the earth has folded up on itself, forming the dome shape that is characteristic of a great number of reservoirs. By surveying and mapping the surface and sub-surface characteristics of a certain area, the geologist can extrapolate which areas are most likely to contain a petroleum or natural gas reservoir. The geologist has many tools at his disposal to do so, from the outcroppings of rocks on the surface or in valleys and gorges, to the geologic information attained from the rock cuttings and samples obtained from the digging of irrigation ditches, water wells, and other oil and gas wells. This information is all combined to allow the geologist to make inferences as to the fluid content, porosity, permeability, age, and formation sequence of the rocks underneath the surface of a particular area. For example, in the picture shown, a geologist may study the outcroppings of rock to gain insight into the geology of the subsurface areas.


Once the geologist has determined an area where it is geologically possible for a natural gas or petroleum formation to exist, further tests can be performed to gain more detailed data about the potential reservoir area. These tests allow for the more accurate mapping of underground formations, most notably those formations that are commonly associated with natural gas and petroleum reservoirs. These tests are commonly performed by a geophysicist, one who uses technology to find and map underground rock formations.


Arguably the biggest breakthrough in petroleum and natural gas exploration came through the use of basic seismology. Seismology refers to the study of how energy, in the form of seismic waves, moves through the Earth's crust and interacts differently with various types of underground formations. In 1855, L. Palmiere developed the first 'seismograph', an instrument used to detect and record earthquakes. This device was able to pick up and record the vibrations of the earth that occur during an earthquake. However, it wasn't until 1921 that this technology was applied to the petroleum industry and used to help locate underground fossil fuel formations.

The basic concept of seismology is quite simple. As the Earth's crust is composed of different layers, each with its own properties, energy (in the form of seismic waves) traveling underground interacts differently with each of these layers. These seismic waves, emitted from a source, will travel through the earth, but also be reflected back toward the source by the different underground layers. Through seismology, geophysicists are able to artificially create vibrations on the surface and record how these vibrations are reflected back to the surface, revealing the properties of the geology beneath.

An analogy that makes intuitive sense is that of bouncing a rubber ball. A rubber ball that is dropped on concrete will bounce in a much different way than a rubber ball dropped on sand. In the same manner, seismic waves sent underground will reflect off dense layers of rock much differently than extremely porous layers of rock, allowing the geologist to infer from seismic data exactly what layers exist underground and at what depth. While the actual use of seismology in practice is quite a bit more complicated and technical, this basic concept still holds.



In practice, using seismology for exploring onshore areas involves artificially creating seismic waves, the reflection of which are then picked up by sensitive pieces of equipment called 'geophones' that are embedded in the ground. The data picked up by these geophones is then transmitted to a seismic recording truck, which records the data for further interpretation by geophysicists and petroleum reservoir engineers. The drawing shows the basic components of a seismic crew. The source of seismic waves (in this case an underground explosion) creates that reflect off the different layers of the Earth, to be picked up by geophones on the surface and relayed to a seismic recording truck to be interpreted and logged.
Although the seismograph was originally developed to measure earthquakes, it was discovered that much the same sort of vibrations and seismic waves could be produced artificially and used to map underground geologic formations. In the early days of seismic exploration, seismic waves were


created using dynamite. These carefully planned, small explosions created the requisite seismic waves, which were then picked up by the geophones, generating data to be interpreted by geophysicists, geologists, and petroleum engineers.

Recently, due to environmental concerns and improved technology, it is often no longer necessary to use explosive charges to generate the needed seismic waves. Instead, most seismic crews use non-explosive seismic technology to generate the required data. This non-explosive technology usually consists of a large heavy-wheeled or tracked-vehicle carrying special equipment designed to create a large impact or series of vibrations. These impacts or vibrations create seismic waves similar to those created by dynamite. In the seismic truck shown, the large piston in the middle is used to create
The same sort of process is used in offshore seismic exploration. When exploring for natural gas that may exist thousands of feet below the seabed floor, which may itself be thousands of feet below sea level, a slightly different method of seismic exploration is used. Instead of trucks and geophones, a ship is used to pick up the seismic data and hydrophones are used to pick up seismic waves underwater. These hydrophones are towed behind the ship in various configurations depending on the needs of the geophysicist. Instead of using dynamite or impacts on the seabed floor, the seismic ship uses a large air gun, which releases bursts of compressed air under the water, creating seismic waves that can travel through the Earth's crust and generate the seismic reflections that are necessary.



In addition to using seismology to gather data concerning the composition of the Earth's crust, the magnetic properties of underground formations can be measured to generate geological and geophysical data. This is accomplished through the use of magnetometers, which are devices that can measure the small differences in the Earth's magnetic field. In the early days of magnetometers, the devices were large and bulky, and only able to survey a small area at a time.


In addition to using variances in the Earth's magnetic field, geophysicists can also measure and record the difference in the Earth's gravitational field to gain a better understanding of what is underground. Different underground formations and rock types all have a slightly different effect on the gravitational field that surrounds the Earth. By measuring these minute differences with very sensitive equipment, geophysicists are able to analyze underground formations and develop clearer insight into the types of formations that may lie below ground, and whether or not the formations have the potential for containing hydrocarbons like natural gas.


The best way to gain a full understanding of subsurface geology and the potential for natural gas deposits to exist in a given area is to drill an exploratory well. This consists of digging into the Earth's crust to allow geologists to study the composition of the underground rock layers in detail. In addition to looking for natural gas and petroleum deposits by drilling an exploratory well, geologists also examine the drill cuttings and fluids to gain a better understanding of the geologic features of the area. Logging, explained below, is another tool used in developed as well as exploratory wells. Drilling an exploratory well is an expensive, time consuming effort. Therefore, exploratory wells are only drilled in areas where other data has indicated a high probability of petroleum formations. For more information on the process of drilling natural gas wells, click here.


Logging refers to performing tests during or after the drilling process to allow geologists and drill operators to monitor the progress of the well drilling and to gain a clearer picture of subsurface formations. There are many different types of logging, in fact; over 100 different logging tests can be performed, but essentially they consist of a variety of tests that illuminate the true composition and characteristics of the different layers of rock that the well passes through. Logging is also essential during the drilling process. Monitoring logs can ensure that the correct drilling equipment is used and that drilling is not continued if unfavorable conditions develop.

It is beyond the scope of this website to get into detail concerning the various types of logging tests that can be performed. Various types of tests include standard, electric, acoustic, radioactivity, density, induction, caliper, directional and nuclear logging, to name but a few. Two of the most prolific and often performed tests include standard logging and electric logging.

Standard logging consists of examining and recording the physical aspects of a well. For example, the drill cuttings (pieces of rock displaced by the drilling of the well) are all examined and recorded, allowing geologists to physically examine the subsurface rock. Also, core samples are taken by lifting a sample of underground rock intact to the surface, allowing the various layers of rock and their thickness to be examined. These cuttings and cores are often examined using powerful microscopes that can magnify the rock up to 2,000 times. This allows the geologist to examine the porosity and fluid content of the subsurface rock, and to gain a better understanding of the earth in which the well is being drilled.

Electric logging consists of lowering a device used to measure the electric resistance of the rock layers in the 'down hole' portion of the well. This is done by running an electric current through the rock formation and measuring the resistance that it encounters along its way. This gives geologists an idea of the fluid content and characteristics. A newer version of electric logging, called induction electric logging, provides much the same types of readings, but is more easily performed and provides data that is more easily interpreted.



The drilling of an exploratory or developing well is the first contact that a geologist or petroleum engineer has with the actual contents of the subsurface geology. Logging, in its many forms, uses this opportunity to gain a fuller understanding of what actually lies beneath the surface. In addition to providing information specific to that particular well, vast archives of historical logs exist for geologists interested in the geologic features of a given or similar area.


There are many sources of data and information for the geologist and geophysicist to use in the exploration for hydrocarbons. However, this raw data alone would be useless without careful and methodical interpretation. Much like putting together a puzzle, the geophysicist uses all of the sources of data available to create a model, or educated guess, as to the structure of the layers of rock under the ground. Some techniques, including seismic exploration, lend themselves well to the construction of a hand- or computer-generated visual interpretation of an underground formation. Other sources of data, such as that obtained from core samples or logging, are taken into account by the geologist when determining the subsurface geological structures. Despite the amazing evolution of technology and exploration techniques, the only way of being sure that a petroleum or natural gas reservoir exists is to drill an exploratory well. Geologists and geophysicists can make their best guesses as to the location of reservoirs, but these are not infallible.


Two-dimensional seismic imaging refers to geophysicists using the data collected from seismic exploration activities to develop a cross-sectional picture of the underground rock formations. The geophysicist interprets the seismic data obtained from the field, taking the vibration recordings of the seismograph and using them to develop a conceptual model of the composition and thickness of the various layers of rock underground. This process is normally used to map underground formations, and to make estimates based on the geologic structures to determine where it is likely that deposits may exist.

Another technique using basic seismic data is known as 'direct detection.' In the mid-1970s, it was discovered that white bands, called 'bright spots', often appeared on seismic recording strips. These white bands could indicate deposits of hydrocarbons. The nature of porous rock that contains natural gas could often result in reflecting stronger seismic reflections than normal, water-filled rock. Therefore, in these circumstances, the actual natural gas reservoir could be detected directly from the seismic data. However, this does not hold universally. Many of these 'bright spots' do not contain hydrocarbons, and many deposits of hydrocarbons are not indicated by white strips on the seismic data. Therefore, although adding a new technique of locating petroleum and natural gas reservoirs, direct detection is not a completely reliable method.

With the development of the microprocessor, it has become relatively easy to use computers to assemble seismic data that is collected from the field. This allows for the processing of very large amounts of data, increasing the reliability and informational content of the seismic model. There are three main types of computer-assisted exploration models: two-dimensional (2-D), three-dimensional (3-D), and most recently, four-dimensional (4-D). These imaging techniques, while relying mainly on seismic data acquired in the field, are becoming more and more sophisticated. Computer technology has advanced so far that it is now possible to incorporate the data obtained from different types of tests, such as logging, production information, and gravimetric testing, which can all be combined to create a 'visualization' of the underground formation. Thus geologists and geophysicists are able to combine all of their sources of data to compile one clear, complete image of subsurface geology. An example of this is shown where a geologist uses an interactive computer generated visualization of 3-D seismic data to explore the subsurface layers.


One of the biggest breakthroughs in computer-aided exploration was the development of three-dimensional (3-D) seismic imaging. Three-D imaging utilizes seismic field data to generate a three dimensional 'picture' of underground formations and geologic features. This, in essence, allows the geophysicist and geologist to see a clear picture of the composition of the Earth's crust in a particular area. This is tremendously useful in allowing for the exploration of petroleum and natural gas, as an actual image could be used to estimate the probability of formations existing in a particular area, and the characteristics of that potential formation. This technology has been extremely successful in raising the success rate of exploration efforts. In fact, using 3-D seismic has been estimated to increase the likelihood of successful reservoir location by 50 percent.


Although this technology is very useful, it is also very costly. Three-D seismic imaging can cost hundreds of thousands of dollars per square mile. The generation of 3-D images requires data to be collected from several thousand locations, as opposed to 2-D imaging, which only requires several hundred data points. As such, 3-D imaging is a much more involved and prolonged process. Therefore, it is usually used in conjunction with other exploration techniques. For example, a geophysicist may use traditional 2-D modeling and examination of geologic features to determine if there is a probability of the presence of natural gas. Once these basic techniques are used, 3-D seismic imaging may be used only in those areas that have a high probability of containing reservoirs.


In addition to broadly locating petroleum reservoirs, 3-D seismic imaging allows for the more accurate placement of wells to be drilled. This increases the productivity of successful wells, allowing for more petroleum and natural gas to be extracted from the ground. In fact, 3-D seismic can increase the recovery rates of productive wells to 40-50 percent, as opposed to 25-30 percent with traditional 2-D exploration techniques.

In addition to broadly locating petroleum reservoirs, 3-D seismic imaging allows for the more accurate placement of wells to be drilled. This increases the productivity of successful wells, allowing for more petroleum and natural gas to be extracted from the ground. In fact, 3-D seismic can increase the recovery rates of productive wells to 40 to 50 percent or greater, as opposed to 25 to 30 percent with traditional 2-D exploration techniques.

Three-D seismic imaging has become an extremely important tool in the search natural gas. By 1980, only 100 3-D seismic imaging tests had been performed. However, by the mid 1990s, 200 to 300 3-D seismic surveys were being performed each year. In 1996, in the Gulf of Mexico, one of the largest natural gas-producing areas in the U.S., nearly 80 percent of wells drilled in the Gulf were based on 3-D seismic data. In 1993, 75 percent of all onshore exploratory surveys conducted used 3-D seismic imaging.


Two-dimensional (2-D) computer-assisted exploration includes generating an image of subsurface geology much in the same manner as in normal 2-D data interpretation. However, with the aid of computer technology, it is possible to generate more detailed maps more quickly than by the traditional method. In addition, with 2-D CAEX it is possible to use color graphic displays generated by a computer to highlight geologic features that may not be apparent using traditional 2-D seismic imaging methods.

While 2-D seismic imaging is less complicated and less detailed than 3-D imaging, it must be noted that 3-D imaging techniques were developed prior to 2-D techniques. Thus, although it does not appear to be the logical progression of techniques, the simpler 2-D imaging techniques were actually an extension of 3-D techniques, not the other way around. Because it is simpler, 2-D imaging is much cheaper, and more easily and quickly performed, than 3-D imaging. Because of this, 2-D CAEX imaging may be used in areas that are somewhat likely to contain natural gas deposits, but not likely enough to justify the full cost and time commitment required by 3-D imaging.


One of the latest breakthroughs in seismic exploration and the modeling of underground rock formations has been the introduction of four-dimensional (4-D) seismic imaging. This type of imaging is an extension of 3-D imaging technology. However, instead of achieving a simple, static image of the underground, in 4-D imaging the changes in structures and properties of underground formations are observed over time. Since the fourth dimension in 4-D imaging is time, it is also referred to as 4-D 'time lapse' imaging.


Various seismic readings of a particular area are taken at different times, and this sequence of data is fed into a powerful computer. The different images are amalgamated to create a 'movie' of what is going on under the ground. By studying how seismic images change over time, geologists can gain a better understanding of many properties of the rock, including underground fluid flow, viscosity, temperature and saturation. Although very important in the exploration process, 4-D seismic images can also be used by petroleum geologists to evaluate the properties of a reservoir, including how it is expected to deplete once petroleum extraction has begun. Using 4-D imaging on a reservoir can increase recovery rates above what can be achieved using 2-D or 3-D imaging. Where the recovery rates using these two types of images are 25 to 30 percent and 40 to 50 percent respectively, the use of 4-D imaging can result in recovery rates of 65 to 70 percent.

Now that we have taken a look at how natural gas deposits are found, the next step in the natural gas line is the process of extraction. Click here to learn how natural gas is taken out of the Earth and brought to the surface.

Petroleum Exploration in Morocco


PETROLEUM,Drilling Activity , Exploration history Prospectivity of Basins, Exploration activity Promotion ,Activities Partnership and cooperation , Exploitation and production activity

Petroleum Exploration in Morocco started early in the last century and covers five major periods:

The period between 1900 and 1928 saw petroleum exploration in the Rharb Basin at the vicinity oil seeps. This led to the discovery of the Ain Hamra oil pool in 1923.The period from 1928 to 1958 saw the creation of BRPM (Bureau de Recherches et d’Exploitations Minières) in 1928, and the SCP (Société Chérifienne de Pétrole) in 1929 that carried out most of petroleum exploration activities.
Seismic reflection techniques were first introduced, in the Rharb and Prerif basins in 1935. It is not until 1955 that this tool was used to explore the Essaouira, Souss and Guercif basins. Oil and gas discoveries were made in the Prerif Ridges and in the Sidi Fili Trend. Cumulative production during this period reached 8 million barrels of oil.

From 1958 to 1981, the Hydrocarbon Law was passed and attracted international investments. Exploration by BRPM and its partners was extended to cover most of the basins of Morocco. Wells drilled during this period revealed commercial oil and gas accumulations in the Essaouira and Rharb Basins. By the end of 1981, cumulative production was 9 million barrels of oil and 35 BCF of gas.From 1981 to 2003, ONAREP (Office National de Recherches et d’Exploitations Pétrolières) was created by the moroccan government, with a mandate to explore for hydrocarbons in Morocco both by itself and jointly with foreign petroleum companies. Since the creation of ONAREP, 85 wells have been drilled, 50 of which were jointly with international companies. This activity led to the discovery of the gas/condensate field at Meskala (Essaouira) and of several biogenic gas accumulations in the Rharb Basin.

The Hydrocarbon Law was amended in 1992 and in 2000 providing Oil and Gas investors with some of the most attractive fiscal terms available internationally.

 In 2003, ONHYM was created as a merger of ONAREP and BRPM, beginning a new era with a dynamic strategy and improved synergy to adequately assess both the Hydrocarbon and Mining Potential of Morocco.



To date, 18 797.25 Km² of 3D seismic and 160 649.00 Km of 2D seismic data have been acquired offshore.  Also, 47 217.00 Km of 2D seismic and 1 283.00 Km² of 3D seismic data have been acquired onshore.

Close analysis of success, and failure, of various exploration programs undertaken in Morocco demonstrate the attractiveness of the hydrocarbon opportunities of the country and suggest new hydrocarbon exploration concepts as well as new prospects awaiting for drilling.

Morocco is underexplored in terms of petroleum exploration and is considered as frontier zones.
The analysis of the data base of the existing wells underlines three important facts:
The number of hydrocarbon exploratory wells is extremely low in most  basins;Many wells did not reach their objectives due to technical problems, or were spudded  off structure;The number of exploration concepts tested so far is very limited.
 It should be noted that exploration drilling activity for hydrocarbons has, so far, been based only on sporadic exploration programs. It therefore lacks the momentum needed to develop exploration ideas and establish efficient guidelines that lead to a discovery. Hydrocarbon discoveries have typically been made only in areas where sustainable effort of continuous exploration programs and adequate exploration drilling activity were undertaken.

Several viable petroleum systems, with good hydrocarbon potential, exist in Moroccan sedimentary basins.
Recent studies, integrating regional synthesis studies with substantial volumes of seismic data, particularly in the offshore, have generated new exploration concepts. These studies have also defined many structures that wait to be drilled.

 SOURCE ROCKS

The data base so far available has permitted the delineation of the following facies as potential source rocks:

Palaeozoic

The Ordovician, Silurian and Devonian organic facies are predominantly sapropelic (type II kerogen) although, in places, these facies are becoming lipidic (type I kerogen). These Palaeozoic organic facies are widespread over the whole Moroccan territory and constitute the continuation of those encountered in Algeria and North Africa in general. The Carboniferous organic facies, however, is predominantly humic (type III kerogen). The Silurian source rocks with TOC value of up to 12 % (Tadla Basin) are the most important. The Ordovician and Devonian sequences exhibit interesting source rock intervals with TOC values in the order of 4 % in the same basin. Visean and Namurian sequences contain shaly intervals with humic organic facies (type III kerogen) having TOC values around 1.5 % in the High Plateaux. Similar facies are also encountered in the Tadla Basin. The Westphalian and the Stephano-Autunian organic facies with frequent coaly and lignitic intervals yielded TOC values in excess of 30 % in the High Plateaux and Argana valley. Some oils sampled from reservoirs or well shows in the Prerif (Tselfate field), Doukkala, Tadla, and Essaouira basins are interpreted to be generated from Palaeozoïc source rocks.


Triassic

The synrift sequence, infilling Triassic graben and half graben along the Atlantic coastal basins, may yield excellent lacustrine (type I kerogen) source rock. These intervals have been tested in the Doukkala Basin. TOC values are in the order of 2.5 %.

Jurassic

Recent geochemical survey shows that the Rif, the Middle and the High Atlas basins contain rich Lower Jurassic (Liassic) source rock. The organic facies is predominantly amorphous type II kerogen with TOC values up to 10 % and within the oil window in most places. This facies is producing oil in the Prerif Ridges and is the source for many seeps distributed throughout the Prerif and the Middle Atlas areas.

The petroliferous character of this Jurassic organic facies may have a widespread distribution. The oil at Sidi Rhalem field in the Essaouira Basin is produced from Oxfordian shale (TOC up to 4 %). The oils produced in the Cap Juby structure in the Tarfaya Basin were probably sourced from Jurassic marly facies. In the Tarfaya-Layoune-Dakhla Basin, Lower and Middle Jurassic organic facies have TOC values ranging from 1.47 to 2.49 %.
Cretaceous

Marine organic facies (Aptian-Albian and Cenomano-Turonian) are, by far, the richest in organic matter with TOC up to 20 %. These facies are widespread over most of Moroccan sedimentary basins. Under adequate burial, the Cretaceous marine organic facies may constitute an excellent effective source rock. Recent synthesis shows that this could be the case in the Rif, Tadla and, basinward, in the offshore Atlantic basins.

Neogene

the Neogene (Oligocene and Miocene) marls and shales have TOC values of up to 7 % in the Atlantic basins and up to 2 % in the Mediterranean offshore area. This source rock produces biogenic gas but can yield oil where sufficiently buried. This is seen particularly in the Rharb Basin where we have either biogenic gas or oil production, depending on the depth of burial of this source rock.

 Reconnaissance survey of the Boujdour coastal area: Interpretation of 2D seismic data acquired in 2007, drilling of a stratigraphic well and study of the regional fracturating. A seismic program of 300 km is planned in the south area of Boujdour.Development of Meskala and Toukimt fields: Interpretation of 3D seismic acquired in late 2007-early 2008 and drilling of a well on the most promising block.Play concepts control of the El Jadida-Ifni offshore segment : 2D/3D seismic interpretation, petroleum reevaluation of the interest area and promotion of free zonesFollow-up of the partners work, including the planned exploration drilling of several wells (Gharb, Prérif, Bouanane, Tanger-Larache Offshore), the seismic acquisition on the Bas Draa, Boudenib, Tarfaya and Haha, and the geological and geophysical studies and the interpretations of the other reconnaissance’s licenses and permits.Stratigraphic datings, geochemical assessment of the formations crossed by ONHYM drilling wells and those planned by the partners. Promotion of the offshore segments of onshore areas of the Eastern Prérif and Southern provinces.Development of petroleum GIS with the transcription of the seismic data and scanning of the well data.Development of a credible and sustainable investment policy for the shared SI.Definition of operating modes between the DSI and the trades to implement the selected SI projects.Developing a portfolio of projects for the 2007-2011 period, classified into four categories.
Partner Exploration Projects are:

Provisional Programs of our partners on the reconnaissance’s zones and permits include:


Geological surveys and reprocessing of seismic data, in the context of regional reconnaissance studies on Guercif, Missour, Tadla, Haouz, High Atlas, Haha, Ouarzazate, Boudenib and Tarfaya onshore basins.2D seismic acquisition campaigns planned for Bas Draa, Haha, Boudenib, Prerif, Gharb and Tarfaya onshore blocks to control play concepts.Assessment of oil recovery prospects defined either in onshore and offshoreDrilling exploration wells on the Tangiers, Tissa-Ouezzane, Tselfat, Asilah, Bouanane permits and on the Gharb Basin blocks, to test various identified prospects.

Exploration Block in Morocco


East West Petroleum has acquired an interest in a large prospectiveexploration block onshore Morocco. The Petroleum Agreement was signed ..portfolio in Morocco. MPE holds two offshore exploration licences (subdivided into 4blocks) and two onshore exploration licences (subdivided into 10 blocks). ...Morocco Blocks, Concessions, Licences, Permits, Major Oilfields and Prospects.Exploration Permits, Exploration Zones, Reconnaissance Contracts, Petroleum ...

Acquisition of Direct Bulgaria and Direct Morocco




TransAtlantic Petroleum Ltd. is pleased to announce that on February 18, 2011, its wholly owned subsidiaries, TransAtlantic Worldwide, Ltd. and TransAtlantic Petroleum Cyprus Limited, acquired 100% of the ownership interests of Direct Petroleum Bulgaria EOOD, Direct Petroleum Morocco, Inc. and Anschutz Morocco Corporation under the terms of the previously announced purchase agreement with Direct Petroleum Exploration, Inc. (Direct). The Company issued 8,924,478 of its common shares to Direct and paid $2.0 million in cash consideration at closing in addition to $492,000 in cash adjustments.



Acquisition of New Exploration Block in Morocco

East West Petroleum Corp. is pleased to announce the Company has acquired an interest in a large prospective exploration block onshore Morocco. The Petroleum Agreement was signed with the Office National des Hydrocarbures et des Mines (“ONHYM”) in Rabat, the country’s capital city.

The 1997 sq. km. (approx. 500,000 acres) Doukkala Block is situated along the Atlantic coast approximately 125 km. southwest from the city of Casablanca. Under the Petroleum Agreement, East West will partner with ONHYM to explore for oil and gas over an 8 year period. The Company will retain a 75% participation interest in the block and operatorship, with ONHYM retaining a 25% participation interest.

The Company will carry out regional geological studies, seismic acquisition and reprocessing, followed by exploratory drilling. Both conventional and unconventional oil plays have been identified on the acreage. Two wells previously drilled on the Block encountered numerous hydrocarbon shows in the Devonian shale section. The Doukkala Block represents East West’s first operated program. The Company is reviewing other opportunities in the country.

Mr. Greg Renwick, President and CEO, commented “the Doukkala Block award represents the Company’s first entry into Morocco and we look forward to working with our new partner ONHYM in pursuing both conventional and unconventional resource plays. ONHYM is a knowledgeable partner which brings many years of experience working in this area”

Mr. Wak Kani, Advisory Board Member of Company commented “Previous drilling on the Doukkala Block demonstrates the presence of hydrocarbon shows in a thick Devonian shale section over a depth range of 1500 to 3000 meters. The Devonian section in Doukkala is of similar age and geology to the emerging unconventional Marcellus shale play in the eastern US.”

Morocco has been attracting more industry attention recently due to the presence of a number of basins which demonstrate the potential to contain unconventional shale resource plays. Recently, companies such as Anadarko and EOG have taken positions in the country. The fiscal terms offered by the Government of Morocco rank amongst the best in the world.

San Leon is pleased to announce that it has completed its work obligations and as a result of the positive results received from this work the Company has successfully negotiated with ONHYM the conversion of the Reconnaissance Licence into a full Exploration Licence which was signed on the 18th of June in Rabat and was approved for release by ONHYM on the 17th July.

San Leon Energy's high resolution aero magnetic survey, which was integrated with surface and subsurface data, indicated some structures; including a 60 km long anticline with the potential for hydrocarbon reserves. The Agreement is valid for up to 8 years and covers a work programme, which includes seismic acquisition and geological studies within the first thirty months.

San Leon operates the Zag Exploration License with a 37.5% stake, partner Island Oil and Gas Plc has a 15% interest, and ONHYM has 25%. The other partner is Long reach Oil and Gas with 22.5%. ONHYM’s 25% interest is free carried until a discovery is made and the development phase is agreed to have commenced.
San Leon Energy Plc is very pleased to announce that it has signed an agreement with ONHYM to employ proprietary In-Situ Vapour Extraction (“IVE”) technology over the 6,000 km2 (1,482,626 acres) Tarfaya Oil Shale project. The agreement was signed with Mrs Amina Benkhadra, General Director of ONHYM and Moroccan Minister of Energy, Mines, Water, and Environment.

San Leon has been working with ONHYM for two years to explore the potential of the available and massive in-place oil shale opportunities. The company has therefore signed a three year Memorandum of Understanding with the Moroccan authorities which grants San Leon exclusivity to convert the area into a License. San Leon estimates reserves of billions of barrels of recoverable oil from the Tarfaya oil shale over the 6,000 km2 area.

To exploit this [potentially vast resource, San Leon has acquired an in-situ oil extraction technology through an agreement with the U.S. company Mountain West Energy (MWE). This technology is exclusive to San Leon in Europe, North Africa and the Middle East. The successful testing of this technology enabled San Leon to successfully apply for the rights to test the large oil shale concession in Morocco.

Laboratory and site testing in the U.S. has been completed and Moroccan site testing will begin later this year. The feasibility study, which includes a work programme, has been presented and agreed in Morocco by ONHYM.

TheTarfaya oil shale has successfully produced 62 litres per tonne in Mountain West Energy’s Utah lab. This is similar to the yield reported by Shell when they were testing in the Tarfaya area from 1981 until 1986. Shell drilled 55 shallow boreholes, all of which were petrophysically logged, in 1982, encountering the Cretaceous and organic rich Tarfaya oil shale within the San Leon area. Shell established an open pit mine and heated the oil shale in a retort for oil production. They left the area in 1986 after oil prices had plunged to $10 per barrel.

IVE is an in-situ oil shale extraction technology that forces heated gas through a central injector well and into a high oil yielding and fractured oil shale. The oil is then produced from several extraction wells, equidistant from the central injection well. IVE was tested successfully in the Naval Petroleum Reserve #3 at the Tea Pot Dome Field in Wyoming, with assistance from the US government, in order to increase production from the existing heavy oil reserves The in-situ process of oil extraction is cleaner environmentally than the alternative technology, open pit mining, which is invasive. San Leon’s IVE process “cooks” the oil shale in the ground (or in-situ) and the gases utilized in the process are recycled within a closed system.

San Leon conducted a detailed test study from August 2008 until January 2009 and produced an extensive report outlining the IVE technology and the prospectivity of the Tarfaya oil shale. On the basis of the Tarfaya Work Study, ONHYM and The Group signed the Tarfaya Oil Shale MOU, which gives San Leon 3 years to test the IVE process.

The first test project is now in the planning stage and The Group expects this to be completed in the first half of 2010. The test site will be selected in a location approximately 200m above the high oil yielding zone within the Tarfaya oil shale. It could take at least a year to mobilize all the essential equipment for San Leon’s first test site.In a similar transaction, Petrobras has recently signed an MOU with ONHYM for the Tarfaya oil shale, neighbouring the San Leon acreage. Petrobras also has the Timhadit oil shale MOU, which lies in the northern part of Morocco.

Phil Thompson, CEO of San Leon commented:
“This is a monumental achievement for our company to add the potential to access huge recoverable oil reserves from the Tarfaya shale through our oil shale technology. We are delighted with this accomplishment as it represents a major step in the development of San Leon. We are particularly pleased to note the strong support given by ONHYM in our negotiations and trials process and look forward to working together to develop the burgeoning Moroccan oil and gas environment.

”Mrs Amina Benkhadra, General Director of ONHYM and Moroccan Minister of Energy, Mines, Water, and Environment commented:
“We are delighted that San Leon has decided to join with international super majors in exploring the potential of our oil shale. Morocco remains committed to developing its oil and gas industry to the highest of international standards and will continue to provide positive support to foreign direct investment, be it through the provision of technical data, or working in co-operation to upgrade the logistical systems in country to allow efficient development”



Caithness Awarded New Acreage of Taounate, Morocco

Caithness Petroleum Limited the privately owned British independent petroleum exploration and production company with assets in onshore Morocco is pleased to announce that the Company’s Moroccan subsidiary, Cabre Maroc Limited, (“Cabre Maroc”) has been awarded a one year reconnaissance licence over the Taounate area in Morocco.

This lies immediately to the northeast of the Company’s Fes exploration permit and is believed to comprise an extension of the geological plays in the Fes block. The Taounate block covers an area of approximately 4,660 km2 and is largely unexplored.

Cabre Maroc is Operator and holds a 75% interest in the licence. The remaining 25% is held by ONHYM, the Moroccan state oil company. When the licence expires, Caithness and ONHYM will have the right to apply for an eight-year exploration permit over the area. Cabre Maroc has arranged to acquire an airborne gravity / gradiometry survey, to identify and map structures in the Taounate licence area.